Investor Presentation - Bowleven PLC...The Presentation may include statements that are, or may be...
Transcript of Investor Presentation - Bowleven PLC...The Presentation may include statements that are, or may be...
JUNE 2013 RBC Global Energy and Power Conference 1
Investor Presentation RBC Conference June 2013
JUNE 2013 RBC Global Energy and Power Conference 2
Disclaimer
Important Notice
Nothing in this presentation or in any accompanying management discussion of this presentation (the "Presentation") constitutes, nor is it intended to
constitute: (i) an invitation or inducement to engage in any investment activity, whether in the USA, Canada, the United Kingdom or in any other jurisdiction;
(ii) any recommendation or advice in respect of the ordinary shares (the "Shares") in Bowleven plc (the "Company"); (iii) any offer for the sale, purchase
or subscription of any Shares; or (iv) any directed selling effort in respect of any Shares.
Cautionary note for US investors
The Shares are not registered under the US Securities Act of 1933 (as amended) (the "Securities Act") and may not be offered, sold or transferred
except pursuant to an exemption from, or in a transaction not subject to, the registration requirements of the Securities Act and in compliance with any other
applicable state securities laws.
The United States Securities and Exchange Commission ("SEC") permits oil and gas companies, in their filings with the SEC, to disclose only proved
reserves that a company has demonstrated by actual production or formation tests to be economically and legally producible under existing economic and
operating conditions. The Company is not required to make filings with the SEC and this presentation includes information on "volumes initially in place",
"STOIIP“, "resources" and other similar terms. Such terms do not refer to and are not reserves and US investors are cautioned accordingly.
Cautionary note for Canadian investors
No securities commission or similar authority in Canada has reviewed or in any way passed upon this presentation or the merits of the Shares, and any
representation to the contrary is an offence.
Forward-looking statements
The Presentation may include statements that are, or may be deemed to be "forward-looking statements". These forward-looking statements can be identified
by the use of forward-looking terminology, including the terms "believes", "estimates", "anticipates", "projects", "expects", "intends", "may", "will", "seeks" or
"should" or, in each case, their negative or other variations or comparable terminology, or by discussions of strategy, plans, objectives, goals, future events or
intentions. These forward-looking statements include all matters that are not historical facts. They include statements regarding the Company's intentions,
beliefs or current expectations concerning, amongst other things, the results of operations, financial conditions, liquidity, prospects, growth and strategies of
the Company and its direct and indirect subsidiaries (the "Group") and the industry in which the Group operates. By their nature, forward-looking
statements involve risks and uncertainties because they relate to events and depend on circumstances that may or may not occur in the future. Forward-
looking statements are not guarantees of future performance. The Group’s actual results of operations, financial conditions and liquidity, and the development
of the industry in which the Group operates, may differ materially from those suggested by the forward-looking statements contained in the Presentation.
Other than in accordance with the Company's obligations under the AIM Rules for Companies, the Company undertakes no obligation to update or revise
publicly any forward-looking statement, whether as a result of new information, future events or otherwise. All written and oral forward-looking statements
attributable to the Company or to persons acting on the Company's behalf are expressly qualified in their entirety by the cautionary statements referred to
above and contained elsewhere in the Presentation.
JUNE 2013 RBC Global Energy and Power Conference 3
Vision & Strategy
• Strategy focused on creating and realising value through
material exploration success and development.
• Seek value adding partnerships and niche acquisitions as
appropriate.
• Fostering strong external partnerships and in-country
relationships.
• Targeted approach to technical, commercial and political risk.
• Resources to Reserves.
Vision
Strategy – Focus on Africa
“It is our vision to build an African focused exploration
and production company which in time becomes
renowned for its ability to consistently create and realise
material shareholder value through exploration led
organic growth and niche acquisitions.”
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Company Overview
• 5 blocks in Cameroon covering 4,644km².
• 3 offshore shallow water, 2 onshore; all operated.
• Multiple hydrocarbon discoveries.
• P50 contingent resource base 203 mmboe* (net).
• Phased Hub & Spoke development planned.
• Continued exploration.
Cameroon
• Block 11B onshore Kenya covering ~14,000km².
• Early stage exploration; Airborne geophysical survey and 2D
seismic acquisition.
• Operated by Adamantine Energy, technical support provided by
Bowleven under a TSA.
* Source: Annual Report 2012. Operator’s volumetrics. Pending update from results of IM-5 well.
Kenya
Kenya
Ethiopia
State back-in rights: Etinde 20%, Bomono 10% (at grant of exploitation licence).
Acreage: 2,328km2
Onshore
Equity Interest:
100%
Operator:
Bowleven Group
Bomono Permit
Nigeria
Cameroon
Acreage: ~14,000km2
Onshore
Equity Interest: 50%
(Adamantine 50%)
Operator:
Adamantine
Block 11B
South Sudan
Corporate
Acreage: 2,316km2
Shallow Offshore
Equity Interest:
75% (CAMOP 25%)
Operator:
Bowleven Group
Etinde Permit
• Cash end April 2013 ~ $42 million, no debt.
• Petrofac: up to $500 million for Stage I development with $60
million IM-5 costs reimbursed at FID.
• High equity positions provide farm-out flexibility.
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Etinde Overview Overview of Gross Unrisked Mean Volumes In place*
*Operator’s estimates.
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Hub and Spoke Development Flexibility for future expansion
• All processing onshore; unmanned offshore platforms.
• Stage I - fields on MLHP-7.
• Stage II - discoveries on MLHP-5 (Sapele).
• Significant flexibility for future expansion.
• Hub location to be optimised to maximise synergies with
fertiliser plant.
• First production anticipated 2016; integrated with fertiliser
timetable
• Offshore (wells and other infrastructure): ~$600 million.
• Onshore (processing & NGLs plant): ~$300 million.
• Development costs subject to phasing and cost
optimisation. To be further refined during FEED.
• Intra Isongo – potential for reduced platform and well
requirements, with associated reduction in costs.
Stage I Development Cost Target (Gross): ~$900 million
Phased Approach
• Oil, condensate and wet gas to hub.
• Liquids stripping and NGL extraction onshore.
• Stage I: 70mmscfd dry gas to fertiliser plant.
• Initially IM/IE? fields; level of IF contribution under
evaluation.
• Initial liquids production ~ 15k-20k boepd* (including LPG’s);
to be updated post integration of IM-5 results.
• Supplemental gas offtake solutions also being considered.
• Intra Isongo – possible reinjection candidate; evaluation
required.
Liquids Focused – Gas Enabled
* Operator projections, currently excludes IF.
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†
Resources to Reserves: The Path to FID*
• Etinde: Ongoing evaluation of material prospectivity; IM-5 Intra
Isongo discovery highlights extensive exploration/appraisal
play.
• Bomono: 2 wells planned prior to end of 2014.
• Kenya: Work programme commencing.
Exploration Strategy
* FID: Final Investment Decision
IM-5: successful appraisal/development well - liquids rich and
fertiliser gas requirements underpinned.
Submission of Etinde Exploitation Authorisation Application
(EEAA); integration of IM-5 results underway.
Fertiliser gas sales term sheet including pricing agreed; signing
ceremony held 22 May 2013.
Access to potential development financing - Petrofac Strategic
Alliance.
FID targeted for H2 2013 subject to:
• EEAA - approval anticipated imminently post IM-5 update.
• Gas Sales - moving to GSA.
• Finance - enhanced project economics post IM-5.
• Fertiliser FID - feasibility study completed moving to FEED.
†
FID
EEAA
Fertiliser FID
(Ferrostaal, SNH,
Proman, Helm)
Finance
Gas Sales
Group Objectives Excellent Progress
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IM-5 Well: Pre-drill targets and results*
Etinde Appraisal/Development Drilling
IM-3
Middle Isongo
Intra Isongo
Upper Isongo
IM-3 (Gas
Condensate
Discovery)
Middle Isongo
Net Pay 37m
Upper Isongo
32m (net) encountered; wet as
prognosed.
Intra Isongo
Log evaluated net pay of
approximately 70m.
Intra Isongo DST
Tested >10,800 boepd from
29m net pay.
(37mmscfd & 4,664 bcpd);
CGR inferred 125bbls/mmscf
(peak 133).
IM-5
• Primary: determine reservoir, fluid
properties and gas composition of
Middle Isongo.
• Secondary: explore potential of
Intra Isongo.
• Upper Isongo expected to be
water bearing.
• Suspended as a
development/production well as
planned.
Objectives
Middle Isongo DST
Results
Middle Isongo
Log evaluated net pay of
approximately 25m.
Middle Isongo DST
Tested >7,000 boepd from
14m net pay.
(23mmscfd & 3,155 bcpd);
CGR inferred 136bbls/mmscf
*Operator’s estimates.
• Condensate-rich gas flowed
on test.
• Combined max. flow rates:
60mmscfd & 7,819 bcpd
(Total >17,800 boepd).
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Upper Isongo
Intra Isongo
Middle Isongo
Seismic Correlation Panel Tying IM Wells
IM-3 IM-5 IM-2 IM-4
Log evaluated
net pay approx. 70m.
Areally extensive Intra
Isongo amplitude response
implies gross reservoir
thickness greater than 35m.
Upper Isongo
Intra Isongo
Middle Isongo
3m net
pay. Below
seismic
resolution
= no
amplitude
response
1 Km
Log evaluated
net pay approx.
25m.
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P99 polygon ~4.5km2
P01 polygon ~30km2
Intra Isongo
IM Field Volumetric Update
Material Volume Addition
• Validation of more than sufficient gas volumes on a P90
basis to meet fertiliser plant requirements.
• Intra Isongo discovery represents material volume addition.
• Liquids rich wet-gas: Middle Isongo (min-max) 80-
200bbl/mmscf, Intra Isongo 100-285bbl/mmscf.
• Combined Mean WGIIP and CIIP increased by 162% and
868% to 1,222 bcf and 184 mmbbls respectively.
Material Volume Addition
*Operator’s estimates. Volumes are presented as gross figures.
The WGIIP figures include NGLs, which comprise condensate and LPGs
Volumes have been derived on a probabilistic basis but totals have been arithmetically summed.
Totalling anything other than mean is statistically incorrect and is provided for illustrative purposes only.
WGIIP (bcf)* P90 P50 P10 Mean
Upper Isongo 81 122 187 129
Middle Isongo 175 389 863 467
Intra Isongo 275 539 1,094 626
Total WGIIP (bcf) 531 1,050 2,144 1,222
CIIP (mmbbls)* P90 P50 P10 Mean
Upper Isongo 5 8 13 9
Middle Isongo 25 56 127 68
Intra Isongo 44 91 193 107
Total CIIP (mmbbls) 74 155 333 184
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Intra Isongo Exploration/Appraisal Upside at discovery horizon and greater interval
*Operator’s estimates. Volumes are presented as gross figures.
The WGIIP figures include NGLs, which comprise condensate and LPGs
Volumes have been derived on a probabilistic basis but totals have been arithmetically summed.
Totalling anything other than mean is statistically incorrect and is provided for illustrative purposes only.
Material Exploration/Appraisal Upside
• IM-5 well has considerably de-risked the Isongo play.
• Seismic response correlates with thick reservoir quality
sands.
• A significant number of additional prospects recognised.
• A number of amplitude based prospects are defined at the
same horizon as the Intra Isongo discovery.
• Further prospects also defined in the intervals immediately
above and below Intra Isongo horizon - “greater interval”.
IE-3
Intra Isongo Unrisked Prospect Volumes*
P90 P50 P10 Mean
Total WGIIP (bcf) 599 1,308 2,943 1,591
Total CIIP (mmbbl) 95 221 517 273
5 Km
Discovered Volumes*
IM Field P90 P50 P10 Mean
Total WGIIP (bcf) 531 1,050 2,144 1,222
Total CIIP (mmbbl) 74 155 333 184
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• Alliance with Petrofac to deliver first production
from Etinde.
• High level basis of development design agreed.
• Provides up to $500 million for Stage I
development with $60 million IM-5 costs
reimbursed at FID.
• Provides access to expertise, purchasing power
and personnel (including engineering, design,
project management, procurement and
training).
• Utilising Petrofac’s extensive expertise.
Strategic Alliance
Hub and Spoke Development Stage I Development Gantt Chart
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• Hydrocarbons discovered at multiple stratigraphic levels.
• Significant in-place volumes discovered across MLHP-5 by
the Sapele and D-1R wells.
• Extensive stratigraphically trapped accumulations.
• Deep Omicron test yields 313-329bbls/mmscf.
• Sapele recoverable reserves ultimately determined by
number of wells, completion type and reservoir connectivity.
• Stage II development anticipates unmanned offshore
platforms integrated with onshore hub facility constructed in
Stage I.
• Utilisation of Stage I hub facilitates sanction of future tie-ins.
• Third party assessment carried out by Sproule in H2 2012
(previously announced) validate Bowleven’s Deep Omicron
in-place fairway volumes.
Sapele & D-1R
Hub and Spoke Development Stage II (MLHP-5)
Independent Volume Assessment
In-Place Volumes
Mean
Bowleven‡ Sproule*
Total mmboe 1,197 1,208
Independent Volume Assessment
‡ Operator’s volumetrics.
*Aggregated discovered and undiscovered volumes.
JUNE 2013 RBC Global Energy and Power Conference 14
Cameroon Overview Further Prospectivity
Douala Basin
• MLHP-5 & 6, OLHP 1 & 2.
• Onshore and shallow
offshore areas.
• Highly prospective
acreage.
• Number of onshore oil
seeps.
• Tertiary and Cretaceous
leads.
• Onshore early exploration
phase on 2D dataset.
• Offshore mature
prospects portfolio on 3D
dataset.
Rio del Rey Basin
• MLHP-7.
• Shallow offshore area.
• Highly prospective
acreage within a proven
active hydrocarbon
system.
• Tertiary oil and gas-
condensate discoveries.
• Established portfolio of
additional Tertiary
prospects.
• Intra Isongo discovery at
IM-5; Material
exploration/appraisal
upside.
Cretaceous Turonian plays accessible in onshore area and
shallow waters.
JUNE 2013 RBC Global Energy and Power Conference 15
Etinde - Further Prospectivity
MLHP-6
MLHP-5
• EEAA envisages additional exploration in exploitation area.
• Extensive deeper prospectivity at Paleocene and Cretaceous
levels. Hydrocarbons encountered with Sapele-1 and Sapele-3.
• Palaeocene Alpha-Epsilon system Mean GIIP 1819bcf*.
• Cretaceous Mean Dry GIIP 1029bcf*.
• Evaluation of prospectivity ongoing.
• Highly prospective acreage given its position between proven
active hydrocarbon systems.
• Variety of exploration play types, Bowleven has 3D seismic
dataset.
*Operator’s volumetrics.
MLHP-7
• A significant number of additional prospects recognised at
Intra Isongo and greater interval.
MLHP-5
MLHP-6
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• 6 deep wells and c.10 shallow wells drilled in the 1950’s.
• Wells and onshore oil seeps prove active hydrocarbon
system.
• Tertiary and Cretaceous structural and stratigraphic traps
defined in area.
• Total 500km 2D seismic acquired by Bowleven.
• New 2D data integrated into existing vintage dataset along
with airborne magnetic/gravity survey and geochemical
datasets which now define a series of structural prospects.
Bomono Overview
Bowleven
2D
Acquisition
Vintage 2D
VOG: Gas and
condensate production
commenced Dec 2011.
Douala
10km
Seeps
Historical
NE SW
JUNE 2013 RBC Global Energy and Power Conference 17
Bomono Exploration
Well Operations
Future
• Exploration well location selected (Zingana-1), planning for
immediate follow-up with second independent exploration well.
• Zingana-1 Prospect - site prepared; drill ready location.
• 2 wells planned prior to end 2014.
• Etinde hub facilities provide additional flexibility in event of
further discoveries.
Prospect
Unrisked Mean
HIIP
Oil mmbbls Associated
Gas bcf Gas bcf
Condensate
mmbbls
Tertiary D & E
Sands. 302 224
Tertiary B & C
Sands. 196 7
Permit Status
• Government approval has been given to move into second
two year exploration phase (to December 2014).
• Farm-out completion delayed; discussions continuing. Also
considering alternative farm-out partners in parallel.
Zingana-1
(Proposed Well)
B & C Sands
D & E Sands
JUNE 2013 RBC Global Energy and Power Conference 18
Kenya
Upcoming Work Programme
• Block-wide high density airborne gravity gradient survey.
• Acquisition of 500km 2D seismic.
• Drilling anticipated 2014.
Geology
• Intersection of N-S trending Tertiary, and NE-SW trending
Cretaceous rift systems.
• 5 basins identified in or fringing the block.
• Existing data suggests basins similar form to Lockichar Basin
(Ngamia-1).
• Significant acreage ~14,000km2.
• Bowleven 50% equity interest.
• Initial 2 year exploration period work programme.
• Operated by Adamantine Energy, technical support provided
by Bowleven under a TSA.
Block 11B
Block
11B
Ngamia-1 Twiga South-1
Paipai-1
■Cretaceous
■Tertiary
Sabisa
JUNE 2013 RBC Global Energy and Power Conference 19
Kenya Block 11B
• Existing vintage seismic and gravity data confirm presence of multiple basins
and structural features closely analogous to successful discoveries to the south.
• Preliminary scouting trip confirms ideal terrain across the Gatome basin for
Vibroseis seismic acquisition.
JUNE 2013 RBC Global Energy and Power Conference 20
Funding Overview
• Cash at end April 2013 approx. $42 million, no debt.
• Petrofac provides up to $500 million for Stage I development;
initial capital investment at FID.
• Potential for up to $60 million of Bowleven’s IM-5 costs at FID.
• High equity interests in Etinde, Bomono and Kenya provide
opportunity to introduce additional farm-in partners if appropriate.
• Investigating new ventures financing for early entry exploration
opportunities.
• Strategic alliance agreement with Petrofac allows further Etinde
farm-down (up to 1/3).
Significant financing flexibility.
JUNE 2013 RBC Global Energy and Power Conference 21
Outlook
• Ongoing evaluation of material Etinde prospectivity.
• Bomono drilling (2 wells planned prior to end of 2014).
• Exploration activities over Kenya acreage (FTG/2D seismic);
drilling anticipated 2014.
Exploration
• Etinde development sanction – the path to FID includes:
• Approval of the EEAA; updated to integrate IM-5 results.
• Finalisation of a Gas Sales Agreement.
• Triggering access to Petrofac funding.
• Progressing phased development activities including pre-
FEED/FEED work.
Resources to Reserves: The Path to Development
Resources to Reserves
Cameroon
Exploration
New Frontiers
(Kenya)
oil & gas
Appendix
JUNE 2013 RBC Global Energy and Power Conference 23
Petrofac Commercial Structure
• 80% of Euroil’s entitlement to cost oil until 130% of amount
invested has been repaid.
• X% of Euroil’s entitlement to profit oil (set at FID) to provide a
money multiple of 2.125 of amount invested, subject to not less
than 20% IRR.
• On Petrofac achieving money multiple of 2.125 and IRR 20%:
X% set at 10% ($500 million case) or 6% ($300 million case).
• On Petrofac achieving money multiple of 2.3 and IRR 20%:
X% set at 5% ($500 million case) or 3% ($300 million case).
• Petrofac’s remuneration ultimately capped at maximum of 50% of
Euroil’s project NPV.
Basis of Petrofac’s Remuneration
Commercial Structure
• Structure provides potential for $300 million or $500 million of
capital.
• Petrofac to be remunerated from Euroil’s share of the Etinde
project cashflows.
Onshore Hub
Offshore
Infrastructure
$300 / $500
million
Share of cost
& profit oil
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C5’s Cond.
ML
HP
-7
ML
HP
-5
Fu
rth
er
Dis
c.
Maximising Liquids Value
• All liquid offtake is marketable internationally i.e. free marketing rights for oil.
• Strong local and pan-African market for Propane & Butane (Cameroon
currently imports from Equatorial Guinea).
• Current concept is phased development.
• Flexibility in gas disposal options maintained.
IM
IE
IF
Omicron Deep &
Lower
Epsilon
D-Discovery
(D-1R)
Other existing &
Future
Discoveries
Oil, Condensate
& up to
90mmscfd of
wet gas
Liquids Stripping
(Primary
Processing)
NGL Plant Up to 80mmscfd
Dry Gas
Power (AES)
Up to 10mmscfd
Fertiliser
(Ferrostaal)
Up to 70mmscfd
LNG
Up to 80mmscfd
Delivery Point Gas Options
C4’s Butane
C3’s Propane Methanol
c.60-70mmscfd
Small Scale
LNG
c.60-70mmscfd
Reinjection
Total Liquids Production
10-15% Shrinkage
3rd
Party
Led
Alte
rnativ
e In
-House S
olu
tions
oil & gas
Principal Contact:
Kerry Crawford
Tel: +44 131 524 5678
Kevin Hart
Tel: +44 131 524 5678
www.bowleven.com
Bowleven Plc.
The Cube
45 Leith Street
Edinburgh
EH1 3AT
United Kingdom