ophir energy plc - seneca college · ophir energy plc: corporate overview african exploration...
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An African Oil & Gas Company
Ophir Energy plc
Ophir Energy plc: Corporate Overview
African Exploration Portfolio• 16 assets, across 8 jurisdictions. • Plays in a mix of proven and emerging
basins.
Experienced Management Team• Strong relationships.• Track record of success.
2008• Equatorial Guinea Block R.• Fortuna and Lykos gas discoveries.
2010/11 activity• Tanzania Blocks 1, 3 and 4.• Pweza, Chewa and Chaza gas
discoveries.
SADR x4Operator
Somaliland x1Operator
AGC x1Operator
Gabon x4Operator
Congo (Brazzaville) x1Non-operator
Equatorial Guinea x1Operator
Tanzania x3Operator
Madagascar x1Operator
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Ophir Stakeholders
*Rig Share Agreements
GOVERNMENTS
SADR, Senegal, Guinea Bissau,
Equatorial Guinea, Gabon, Congo (B),
Tanzania, Madagascar, Somaliland
SHAREHOLDERS
Mittal Investments, Mvelaphanda,
Och-Ziff, Kulczyk Group,
Lansdowne, York,
Ospraie, JP Morgan,
Artemis
BG, Premier, Kufpec, RAKGas, Rocksource,
FAR, Wilton,ExxonMobil*PARTNERS
African Oil & Gas Exploration and Appraisal
Experienced Board & Management team
Track RecordStrong Geoscience Skills
Deepwater Operator
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Gas in Africa: Why Find More? 4
LNG is the transportation mechanism that can take gas from Africa to markets in North America, Europe and Asia BUT if the brightest thing on the African continent is
natural gas being flared why would we try to find more?
An Inconvenient Unconventional Truth 5
North Atlantic gas prices dramatically reduced and decoupled from oil prices due to impact of unconventional gas.
50% of US gas demand is from unconventionals in 2010 and predicted to be 70% by 2030.
Unconventional gas has made US the number one global gas producer ahead of Russia.
Switching of some US gasification facilities (import) to liquefaction (export).
Demand for LNG from the US has disappeared with knock-on effects on other markets.
More than 30MMtpa of unconventional LNG from Australia by 2030.
More than 400Tcf of global unconventional potential in addition to the US and Australia.
With a seeming abundance of unconventional gas available why find more in Africa?
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U$/Mcf
US Natural Gas Wellhead Prices
Source: www.eia.doe.gov
Source: The Economist
Another Inconvenient Unconventional Truth 6
Unconventional gas production increased in the US facilitated by the 2005 Energy Bill
which granted certain exemptions from the Clean Water Act, the Clean Air Act, Safe
Drinking Water Act.
Hydraulic frac’ing can use 2 to 7 million gallons of water per frac and up to 20 tons of chemicals per million gallons of water.
This produces a significant volume of waste water contaminated with chemicals.
Opponents of unconventional gas production claim that contamination of
ground water is commonplace.
The public are becoming used to seeing pictures of burning tap water alleged to be caused by frac’ing beneath the level of the
water table.
Source: www.gaslandthemovie.com
Lets Not Give Up On Conventional Just Yet 7
"We see limitations in terms of the environmental footprint and the
infrastructure requirements such as the number of wells we have to build and the technologies that make it a bit challenging
in Europe." Jan Panek, Head of European Commission for Coal & Oil
June 2010.
The industry will no doubt find a way to exploit unconventional gas resources in a
manner that is politically and environmentally sustainable…
…but it will not be as easy, as cheap and as widespread as might have been imagined.
African LNG Will Have a Role to Play 8
LNG will be an important part of the global energy mix in the future. Africa has an abundance of reserves on the west coast, with the east cost emerging as a major gas province.
"We see the potential of East Africa challenging leading LNG production countries including Qatar and Australia by 2030." Jeffries International Ltd, January 2011
So, what role is there for an upstream player such as Ophir?
Comoros
Seychelles
Songo Songo
Block 4
Mafia Deep ST-1
Block 3
Block 1Mnazi Bay
Windjammer
Pweza-1
BarquentineCollier
Ironclad
Blocks 1, 3 and 427,000km2
Ophir (Operator) 40%BG 60%
Chaza-1
Chewa-1
Tanzania: Block Geography 9
Tanzania Blocks 1, 3 and 4: Geo-schematic Section
• Multiple play systems with abundant direct hydrocarbon indicators (DHIs)• Evidence of both oil and gas charge but expectation weighted towards gas• Requirement to pre-plan the commercialisation structure for gas development
4H,1V
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Aggressive Programme to Date
In the period 2006 to 2010 Ophir has:
• Acquired 8,066km 2D seismic data
• Acquired 3,499km2 3D seismic data
• Negotiated gas commercialisation agreements
• Developed a deepwater oilfield supply base at Mtwara and negotiated cooperation agreements to share the facilities with other Operators
In the period 2010 to 2011 Ophir has:
• Introduced BG as a joint venture partner
• Drilled three gas discoveries
• Acquired a further 4,000km2 of 3D seismic data
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Prospect 1 Prospect 2
3D opacity volume showing far offset stack over one of the Prospect 1 reservoirs. The presence of gas is interpreted to cause brightening of the seismic reflectors
and the base of the gas corresponds to a prominent flat event
Interpreted HC Contact
A variety of structural and stratigraphic trapping styles are recognised in Blocks 1,
3 and 4.
Many of the prospects are supported by the presence of DHIs on seismic data resulting in
a reduction of exploration risk.
Tanzania: Sample Prospects 12
Key Success Factors 3: Commercial 13
• On 26 May 2010 the Company entered into a series of gas commercialisation agreements with the Government of Tanzania.
• These provide specific fiscal terms for gas developments and go beyond the PSC to enable the transportation, liquefaction and export of gas to world markets.
• There is also the provision for the supply of gas to local markets thereby ensuring direct stimulation of the Tanzanian economy in addition to export earnings.
• This agreement should allow for an accelerated project schedule.
Commenced drilling offshore Tanzania18 September 2010
Pweza-1: Gas Discovery Chewa-1: Gas Discovery Chaza-1: Gas Discovery
Deepsea Stavanger 14
• Successful deepwater drilling programme underway.
• Pweza, Chewa and Chaza discoveries demonstrate presence of multiple play systems.
• Significant upside potential.
• Further 3D data acquisition underway.
• Shorebase support facilities established.
• Gas commercialisation agreements in place.
• Strong joint venture with a world class LNG developer and supportive Government.
• Resource potential for multi-train LNG project.
• Ideal location for export to Far East markets.
Tanzania: Current Status
Songo Songo
Block 4
Mafia Deep ST-1
Block 3
Block 1Mnazi Bay
Pweza-1
Chaza-1
Chewa-1
Blocks 1, 3 and 427,000km2
Ophir (Operator) 40%BG 60%
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Lykos-1 26m gas column
Fortuna-1 300m gas column
2008 3 Wells2 Gas DiscoveriesEvidence of Oil Charge
2009 1,000km2 3D SeismicConceptual Field Design
2011 Drilling & Production Testing**subject to the usual government consents.
Block R1,600km2
Ophir (Operator) 80%GEPetrol 20%
Equatorial Guinea 16
Block R: 2008 Drilling Campaign
Targ
et I
nte
rval
Pri
nci
pal
S
ourc
e R
ocks
Fan system stratigraphic traps
Crestal four-way dip closures
Deep thrust related closures
Fortuna-1Bythos-1Lykos-1
2008 drilling campaign3 wells in 45 days
Gas discovery
Oil shows Well location Projected well location
Fortuna wd 1,691m TD 3,400m Bythos wd 1,716m TD 4,222mLykos wd 1,536m TD 2,297m
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Risk Mitigation 1: Volume Assurance
• Two discoveries from three wells.
• Positive exploration outcome, but overall project volumes remain to be determined:
in existing discoveries through focussed appraisal;
addition of new low-risk "step-out" gas volumes; and
identification of new resource potential.
Volume
Co
nfi
den
ce
Fortuna
Step out exploration
New resource potential
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Fortuna: Reducing Uncertainty Existing Discoveries
• The Fortuna fan complex is well defined seismically.
• Detailed seismic stratigraphy studies have enabled a full understanding of the depositional architecture.
• The key uncertainty is the net:gross ratio of the sand.
• This will require focussed appraisal drilling.
• The seismic response of hydrocarbons has been calibrated and used to constrain potential resource volumes.
Strike
Probable Gas Water ContactProbable Gas Water Contact
Fortuna-1
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Lykos and Low Risk Step-out Exploration
• Lykos has a proven play-type with significant follow-up potential.
• The features are well defined seismically and have a typical exploration PoS >80%.
• Wells can be drilled and completed as development wells to reduce project costs.
• Many have deeper potential oil targets which can be tested at minimal incremental cost.
• The challenge will be to optimise volume definition and project economics.
Lykos-1
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• Interpretation of the Fortuna 3D is ongoing.
• A number of potential drilling targets have been identified.
• The prospects are well defined seismically, with direct hydrocarbon indicators.
• They have the potential to significantly add to the potential hydrocarbon volumes in Block R.
Fortuna 3D Survey: New Outboard Prospectivity
Amplitude Shutoff
Fortuna Discovery
Area : 44 km2
VolturnasProspect
Area : 48 km2
Chronos Prospect
Area : >75 km2
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FPU with Trunkline to LNG Plant
FPU Vessel
Phase 1
Phase 2
Field Design Basis
• Ophir is committed to supporting the Government’s plans for a second liquefaction train (EGLNG2) as the preferred option to commercialise Block R gas.
• Gas rates 250, 300 and 500MMscfd(subsea pipelines optimised for each rate).
• FPU moored over field.
• Gas dehydration, compression and export of dry gas.
• Export pipeline to Bioko Island to new LNG gas train.
Export Pipeline
Sizing
• 20" - 250MMscfd
• 24" - 500MMscfd
Routing
• 145km - direct to Bioko Island
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Block R: Resource Summary
Fortuna Complex
Low-riskstep-out
exploration
New exploration potential
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Fortuna Low risk step-out exploration
New exploration
Cu
mu
lati
ve r
esou
rces
(T
cf)
• The gas response on Seismic provides a measure of confidence in estimating potential volumes.
• Current resource estimates require confirmation by further exploration and appraisal drilling:
• Fortuna fan 1.0 to 2.0Tcf
• Lykos Play 1.0 to 2.0Tcf
• YTF 0.5 to 5.0Tcf
• Gas discovered to date is dry with no impurities. Ideal for liquefaction.
• Drilling costs are low.
• Conceptual field designs suggest extended production rate of c 250 to 500MMscfd should be possible.
• Development via pipeline to the planned EGLNG2.
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Summary and Conclusions 24
Is there really a place for the juniors in the global LNG business?
We think there is, provided that there is:• Careful choice of geography and geology.• Early entry.• Strong relationships and trust with host Governments.• High quality, well paced and properly funded exploration programmes.• Know when to "phone a friend" and bring in partners.