nautical 020610 out look
DESCRIPTION
Heavy OilTRANSCRIPT
Nautical Petroleum is a research client of Edison Investment Research Limited
2 June 2010
Nautical Petroleum (NPE) has three legs to its story: Kraken, Mariner and a significant
exploration and appraisal portfolio. NPE trades at a significant discount to our 326p
core NAV. Underlying this is scepticism around NPE’s ability to bring its core Kraken
and Mariner projects to fruition and the ability to finance them. For Kraken a dual
penetration well in Q310 has the potential to move it to FDP submission and in our
view NPE’s c 35% share of the £315m cap-ex required to reach the production
phase can be financed given the size of the field. With Mariner, Statoil (45% WI) is
moving towards Project Preliminary Sanction by end 2010, an internal decision gate
that will remove significant uncertainty on whether the 369mmbbl field is going to be
developed. Statoil recently sold a 40% stake in a similar field for $3bn and this
suggests strong motivation to repeat the success. With all this activity coming up,
the investor perspective on NPE has the potential to be transformed by end 2010.
Key events in 2010 for Kraken and Mariner
2010 is an important year for NPE, with key milestones expected on both Kraken and
Mariner, NPE’s two core projects. In Kraken, NPE will drill a dual penetration
appraisal and exploration well in Q310. The result of the appraisal well will be crucial
for a successful FDP submission at the end of 2010. In Mariner, partner and operator
Statoil is on track and expected to reach an internal decision gate by end 2010
(Decision Gate 2 – Project Preliminary Sanction). Project Preliminary Sanction should
be the precursor to the submission of the FDP, expected by end 2011.
Funding: Expected to raise debt to finance capex
NPE reported at H110 a cash position of £16.8m. This should allow it to fund the
Kraken drilling activity and see Mariner through to Project Preliminary Sanction. If all
goes to plan, and the appraisal well is successful, NPE is expected to ramp up capex
during 2011. The bulk of this spend in FY11 is expected to be debt financed.
Valuation: Core NAV of 326p
NPE’s core NAV of 326p is significantly ahead of its current share price. To put this in
context, NPE’s current EV of $22.8m means that its interests in Kraken and Mariner
(119mmbbls) is trading at $0.18/bbl – the lowest in the North Sea peer group.
Outlook
Price 51p
Market Cap £32m
Share price graph
Share details
Code NPE
Listing AIM
Sector Oil & Gas
Shares in issue 63.41m
Price
52 week High Low
73.5p 42.0p
Balance Sheet as at 31 December 2009
Debt/Equity (%) N/A
Core NAV (p) 326
RENAV (p) 445
Net cash (£m) 16.8
Business
Nautical Petroleum is an AIM-listed oil
and gas exploration and production
company, with assets in the UK North
Sea and France.
Valuation
2009 2010e 2011e
P/E relative N/A N/A N/A
P/CF N/A N/A N/A
EV/Sales N/A N/A N/A
ROE N/A N/A N/A
Revenues by geography
UK Europe US Other
100% 0% 0% 0%
Analysts
Neil Shah 020 3077 5715
Elaine Reynolds 020 3077 5700
Peter J Dupont 020 3077 5700
Nautical Petroleum
Year
End
Revenue
(£m)
PBT*
(£m)
EPS*
(p)
DPS
(p)
P/E
(x)
Yield
(%)
06/08 0.0 (1.3) (2.1) 0.0 N/A N/A
06/09 0.0 (0.1) 1.0 0.0 N/A N/A
06/10e 0.1 (3.7) (5.8) 0.0 N/A N/A
06/11e 0.1 (5.9) (9.2) 0.0 N/A N/A
Note: *PBT and EPS are normalised, excluding goodwill amortisation and exceptional items.
Investment summary: 2010 a decisive year
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Investment summary: 2010 a decisive year
Company description: Heavy oil specialist
Nautical Petroleum’s strategy is to acquire and develop heavy oil reserves in the North Sea and
Europe. Its two flagship projects, Kraken and Mariner, are progressing to the FDP stage with first oil
expected in 2012 and 2015, respectively. The company is also involved in a number of exploration
and appraisal prospects, with the Catcher exploration well spudded in May 2010, and the recent
acquisition of the Baltimore discovery offshore Ireland demonstrating Nautical’s ambition to
continue to develop heavy oil beyond Kraken and Mariner.
Heavy oil now accounts for 10% of the UK’s crude production. Although it is harder to extract oil
from these reservoirs, horizontal wells, smarter completions and longer lasting pumps are
transforming the economics of these fields. We see Nautical as well placed to take advantage of
this specialist area.
Sector positioning: Nautical has all the criteria we look for
We believe Nautical meets our criteria to optimise the risk/reward balance for shareholders.
Good subsurface understanding. In Kraken, Nautical drilled 92b-3 in 2008 on the outer flank of the
field. A successful outcome would have proved significant upside resources and maximised value.
Although the sand was absent in this well, Nautical has subsequently carried out extensive
technical work, which has given it a better understanding of the areal extent of the field and has
significantly de-risked the upcoming final appraisal well before FDP submission.
Efficient use of capital. In Mariner, Nautical only needs to spend £3m to get to Decision Gate 2
(DG2), Statoil’s internal decision point, leading to likely project sanction in 2011. For minimal spend
the company can remove significant uncertainty around whether Mariner will be developed. The
recent sale by Statoil of a 40% stake in Peregrino (a similar heavy oil field to Mariner) for $3bn
demonstrates the potential value uplift associated with progressing the Mariner project past the
FDP submission stage.
Activity in the near term. With a final appraisal well on Kraken in Q310, and DG2 on Mariner at end
2010, activity on its two main assets could transform the company this year. The recent farm-in to
Baltimore extends Nautical’s heavy oil portfolio and further establishes Nautical as a key player in
the heavy oil sector.
Key facts
• Net ‘best estimate’ contingent resources 130.1mmboe.
• Net ‘best estimate’ prospective resources 178.3mmboe.
• Debt free and net cash of £16.8m at end December 2009.
• £7.5m undrawn secured debt facility in place.
• Near-term development of Kraken and Mariner with FDP submission targets of end
2010 for Kraken and end 2011 for Mariner.
• Significant portfolio of further exploration and appraisal assets.
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Recent news flow/upcoming catalysts
• The Keddington (WI 10%) development well sidetrack to boost production from 50
barrels of oil a day (bopd) to 150-200bopd commenced on 15 April 2010.
• The Catcher exploration well (WI 15%, 20% carry), operated by Encore Oil targeting
gross prospective resources of 21mmbbl in the initial vertical well spudded on 17 May
2010. Results from the drilling are expected this month.
• Nautical has secured a rig and will drill a dual penetration well in Q310. Success should
lead to an FDP submission by the end of 2010.
• Statoil is working to a key decision point (DG2) on the Mariner development at the end
of 2010. Progression through this point will be a clear indication of Statoil’s intention to
develop Mariner.
Valuation: Core NAV of 326p
Nautical is trading at a significant discount to its core net asset value (NAV) of 326p. We attribute
this to disappointment over the last Kraken well result, shareholder doubt around the development
of Mariner and Nautical’s ability to finance its key projects. With the upcoming drilling campaign at
Kraken and Statoil moving to a key decision point on Mariner, we believe that these factors can be
put behind the company, with the potential to unlock significant value. Comparing Nautical to other
peers on a resource basis is difficult as the company only reports contingent resources, which
cannot be compared with 2P resources without making significant assumptions. However, Xcite
Energy also has contingent resources in the North Sea and, based on its current share price,
Nautical is trading at a 73% discount at a point where it is ready to drill with a rig secured and site
survey completed. There is further near-term exploration upside of a 120p with our risked
exploration net asset value (RENAV) at 445p.
Sensitivities: Pivotal decision points and funding are key
• Kraken appraisal well outcome. The appraisal well must find oil for the Kraken project to
proceed, though the risk of failure has been mitigated by the extensive technical work
carried out by Nautical.
• Mariner DG2 approval from operator Statoil. Nautical is dependent on Statoil for the
approval and timing of the project.
• Funding. Capital expenditure on Kraken and Mariner following project approval will be
substantial for Nautical, although once an FDP has been approved Nautical will have
multiple options to for these projects.
Financials: Capex spend is expected to accelerate
Nautical has two key areas of expenditure in FY11/FY12:
• Spend on bringing Kraken to production is expected to be around £315m, with £44m
falling in FY11 and £261m in FY12. Due to Nautical’s partner Canamens Energy North
Sea (Canamens) opting out of the appraisal well, Nautical is funding 70% of the initial
drilling and testing costs. If the appraisal well is successful provisions exist in the Joint
Operating Agreement that would allow Canamens to buy back into the project. This
would allow Nautical to recover 35% of the gross drilling and testing costs from
Canamens together with a further 35% due to Nautical following FDP, reducing
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Nautical’s equity funding requirements for the Phase 1 development. In the unlikely
event that Canamens does not want to participate following a successful appraisal,
Nautical is likely to farm down its effective 70% working interest.
• A further £5m is expected to be spent on Mariner following Statoil’s Decision Gate 2
process to reach the submission of an FDP. A successful FDP submission would leave
Nautical with a range of options to crystallise value in Mariner.
Company description: Heavy oil in the UKCS
Nautical Petroleum is a hydrocarbon exploration and development company focused on the
acquisition and development of heavy oil in the United Kingdom Continental Shelf and Europe.
Nautical’s key assets are the Kraken and Mariner development projects, which will both pass key
milestones in 2010. The company also holds interests in a number of offshore licences including
Catcher and Baltimore, in addition to the UK onshore producing field Keddington, and onshore
prospects in France.
Heavy oil: Technology developments transform commerciality
Heavy oils are usually defined as those oils having an API oil gravity (a measure of surface density)
less than 22°. Kraken and Mariner each have an API gravity of around 14°. The API gravity of the oil
is not necessarily an indicator of its producibility, so it is more useful to look at oil viscosity as the
key fluid property: an oil with a viscosity greater than 5cp is considered heavy. With viscosities of
110cp in Kraken and 65cp in Mariner (Maureen reservoir), the fields can be compared most closely
to the producing Captain field operated by Chevron, which has a viscosity of 88cp.
Captain came on-stream in 1997. It continues to produce at 25,000bopd and pioneered many of
the innovative horizontal drilling methods and completion technologies required to develop such a
field. The viscosity of the oil in the Heimdal reservoir in Mariner is greater at 540cp, which is more
comparable to that of Statoil’s Bressay development project, but still significantly less than the
600-1,100cp seen in Xcite Energy’s Bentley field. As a heavy oil specialist, and by working with the
major Statoil on Mariner, we see Nautical as well placed to meet the challenges of developing these
fields.
Development projects
Kraken (WI 35%, operator)
• Nautical holds a 35% working interest and is operator of Kraken. The field contains best
estimate contingent resources of 83mmbbl gross (29mmbbl net), and the company will
drill a dual penetration well in Q310, which will consist of an appraisal well and an
exploration well. The appraisal well will assess the southern extent of the existing
hydrocarbon accumulation confirmed by the 9/2-1A and 9/2b-2 wells. The key purpose
of the well will be to recover cores and fluid samples which will be used to optimise the
planned field development. The outcome of this appraisal well is crucial to Nautical’s
plan to submit an FDP, which is scheduled for submission at the end of 2010. The
exploration well, to the west of the appraisal activity, will target gross best estimate
prospective resources of 114mmbbls (net 40mmbbls).
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• In 2008, Nautical drilled appraisal well 9/2b-3 to test the upside of the fields resources,
however, the sandstone was found to be absent. While disappointing, we believe the
upside was significant enough to warrant this higher risk well.
• Following this result and in order to de-risk the upcoming drilling activity, Nautical has
carried out extensive technical work, including a Controlled Source Electromagnetic
survey (CSEM) and a depositional (sand distribution) modelling study. CSEM is a state of
the art technology that detects resistance associated with hydrocarbons. It has been
shown that wells drilled in areas with a CSEM anomaly have a discovery rate two times
above those without such an anomaly. Nautical’s CSEM work indicates an anomaly over
the 9/2b-1A and 9/2b-2 wells, which crucially extends to the south of 9/2b-1A and to
the west of the fault, where the upcoming drilling activity will occur.
Exhibit 1: Kraken field
=Source: Nautical Petroleum
Exhibit 2: Kraken operator’s development schedule
Jan-10 2010 2011 2012
Today
Jul-10 Jan-11 Jul-11 Dec-11 Jun-12 Dec-12
Prepare FDP
FEED
Facilities EPC
Production
PlanningKraken-D Well Planning
Drill Kraken-D
Analyse Kraken-D Results
Prepare FDP
FDP Approved
FEED
Facilities EPC
Drill Development wells 4xP +1xWI
Kraken Production
=Source: Nautical Petroleum
• Kraken will be produced via a wellhead platform and FPSO. Phase 1 of the development
anticipates that four horizontal producers and one vertical water injector will achieve a
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plateau production rate of 30,000bopd. The gross development capex for Kraken for
Phase 1 is estimated at £315m, with spend expected to be phased £44m in 2011 and
£261m in 2012. Nautical expects success in the upcoming exploration activity to the
west of the upcoming appraisal well to form the basis of Phase 2 of the development.
• Canamens, one of Nautical’s partners, will not participate in the drilling at this time. As a
consequence, Nautical will fund 70% of the upcoming drilling activity, while Celtic Oil,
Nautical’s other JV partner, will fund the remaining 30%. The Joint Operating Agreement
(JOA) has provisions to allow Canamens to buy back into the project following the
completion of drilling, subject to refunding Nautical’s additional costs and paying
Nautical an additional financial uplift upon FDP submission.
• We expect production to commence at the end of 2012.
Mariner (WI 26.67%, Statoil operator)
• Nautical holds a 26.67% interest in Mariner, which will be operated by Statoil. Statoil is a
premier heavy oil developer and operates the Grane and Heidrun fields in Norway,
Bressay in the UK and Peregrino in Brazil. Mariner contains best estimate contingent
resources of 369mmbbl gross (90.3mmbbl net) and is therefore significantly larger than
Kraken. An extended well test in 1997 achieved flow rates of 15,000bbl/d from the
Maureen reservoir. Statoil is due to reach its own internal decision point, DG2, by the
end of 2010 with a view to submitting an FDP by late 2011. It is worth noting that any
Statoil project that has gone through DG2 has always gone on to be developed.
Exhibit 3: Mariner schedule
2008 2009 20112010 2012
Production Profiles
Basis of Design
FEED
Freeze design
Concept Shortlist
Concept Selection
EIA
Mariner 3D seismic survey
Mariner OBC seismic survey
G&G/reservoir modelling – Maureen-- Heimdal
Engineering studies
Design Basisproject planning and optionsconcept screeningconcept studiesmature base case
Front End Engineering Design
Environmental Impact Assessment
Field Development Programme
Operator and JV Decision Gates 1 2 3
DECC discussions & FDP Submit FDP
Project SanctionToday
Concept Phase Definition Phase Execution Phase
key JV decision / action points subsurface studies engineering work
Production Profiles
=Source: Nautical Petroleum
• The field is likely to be developed with a large platform of up to 40 slots with most
processing carried out on the platform and exporting via an FSO. The wells will be multi-
lateral, with most wells targeting the larger Heimdal reservoir and the remainder
accessing the Maureen reservoir. Nautical is expected to spend £3m to bring the
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project to DG2 and a further £5m to FDP submission. We see material crystallisation of
value as each stage (DG2 and FDP submission) is reached. First oil is planned for 2015.
Exploration and appraisal portfolio: Options beyond Kraken/Mariner
Nautical has a portfolio of exploration and appraisal prospects:
• Catcher (WI 15%). The exploration well spudded in May 2010, targeting net best
estimate prospective resources of 3.3mmbo. If successful, two contingent sidetracks
will be drilled to with potential upside of 25mmbbl net.
• Baltimore. Nautical acquired a 40% interest in the Baltimore heavy oil discovery (License
Option 10/1) in April 2010. In place resources are estimated at 300mmbbl and the
company will fund a development study to assess its commercial viability.
• Merrow (WI 50%) is located on the edge of the East Irish Sea Basin and is expected to
be farmed out. It has gross prospective resources of 300bcf (net 150bcf) and an
exploration well is expected in 2011.
• Tudor Rose (WI 20%), best estimate contingent resources of 9.8mmbbl (net) in the
Outer Moray Firth.
• Spaniards (WI 30%) is operated by Encore Oil. Following seismic reprocessing a
decision to drill or drop is expected to be taken.
• St Laurent (22% WI) is located in the Aquitaine Basin, south-west France. Nautical is
currently in farm-out negotiations regarding the Audignon Ridge prospect, which has
gross prospective resources of 3.3tcf (net 660bcf).
Production: Keddington oil field
Nautical has a 10% interest in the Keddington oil field in Lincolnshire, which currently produces at
50bopd. A horizontal sidetrack to boost production to 150-200bopd was spudded on 15 April 2010.=
Key management: Steeped with experience
Steve Jenkins, CEO: Mr Jenkins has spent 27 years in the oil and gas industry. Having graduated
with an MSc in Petroleum Geology from Imperial College, he spent 11 years as business
development and HSE manager at Nimir Petroleum and has previous experience of heavy oilfields
from onshore Colombia and Kazakhstan. He is currently chairman of the Oil & Gas Independents
Association (OGIA), and a director of Oil & Gas UK.
Paul Jennings, Commercial Director, has over 30 years in the oil and gas sector in roles covering
accountant, economist and business development. He worked with BP for 17 years with
responsibility for projects in China, Russia, Mongolia, Mozambique and west Africa. After leaving
BP he established exploration and production companies in both Russia and Nigeria, before jointly
founding Nautical Petroleum with Steve Jenkins.
Will Mathers, FD: Mr Mathers spent six years as an accountant with Deloitte specialising in the
energy and mining sectors before joining Woodside Petroleum, holding financial roles in the US and
Australia. Prior to joining Nautical, he was global office controller for Shell Gas (LPG) in London.
John Conlin, Chairman: Mr Conlin has spent 34 years in the oil and gas industry, including 28 years
of extensive international experience with Royal Dutch Shell. A petroleum engineer by background,
he has worked in a variety of senior technical and management positions. Prior to joining Nautical,
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he was a non-executive director of Hardman Resources and Delphian Technology, and chairman
of Fuelture.
Sensitivities: Oil price and appraisal are the risks to
focus on
Oil price risk: Significant headroom to project break-even points
As in all oil and gas projects, commodity prices are of critical importance in determining viability. For
Nautical, the break-even oil price, including all taxes, is $35/bbl for Kraken and $50/bbl for Mariner
(these figures are provided by Nautical). With oil prices in May 2010 at $75/bbl, there is headroom
for these projects to remain economic.
Appraisal risk
The outcome of the Kraken appraisal well is critical to the continuation of the project. This risk has
been mitigated by the extensive technical work carried out by the company.
Approval risk: In the hands of Statoil for Mariner
As a non-operator on Mariner, Nautical is dependent on decisions from operator Statoil regarding
the approval, priority and timing of the project. However, again the risk is somewhat mitigated as
from here there is minimal capital spend incurred by Nautical to bring the project to DG2.
Financial risk: Significant capex spend will require funding
Development capex for Kraken and Mariner is substantial. Nautical’s end December 2009 balance
sheet was debt free with net cash of £16.8m. Based on our current financial projections, the
company is likely to have to raise additional funds in the run up to 2011 in order to meet its capex
plans, and has signalled that the bulk of this is expected to be debt financed.
Political risk: Low
With exposure in UKCS and Europe, Nautical’s political risk is very low.
Valuation: Trading below peer multiples and core NAV
Our valuation approach combines an absolute valuation with a cross check against peer and
recent transaction multiples. Exhibit 5 summarises our valuation of Nautical’s assets.
Relative positioning: Xcite and Peregrino suggest upside to shares
Exhibit 4 shows Nautical relative to a group of North Sea peers in terms of resource. The great
difficulty in an EV/boe peer comparison with this peer group is that Nautical has 2C or contingent
resources, which are strictly not comparable with 2P reserves. There is one company in the peer
group that also has contingent resources: Xcite Energy. Xcite’s Bentley field has independently
assessed contingent resources of 122.5mmbbls on a most likely basis. Management recently
upgraded their resource estimate following 3D seismic to 160mmbbls. Xcite is currently trading at
an EV of c $99m (market cap less current net cash). This would suggest it is trading at $0.57/boe
based on upgraded contingent resources. On the same basis, Nautical’s current EV of $22.8m
leaves it trading at $0.18/boe based on its contingent resources of 130mmbbls.
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The upside of developing these resources into 2P and moving to production can be seen in the
multiple recently paid by Sinochem for a 40% stake in Statoil’s Peregrino field. The Peregrino field
is a heavy oil field located 85km offshore in Brazil’s Campos basin and is estimated to contain
recoverable reserves of between 300-600mmbbls, with production due to start in 2011. The field
lies in shallow water of between 328 and 390 feet and has a heavy crude of 13° API with high
viscosity. Sinochem paid $3bn for a 40% stake or between $12.5-25/bbl. While under a different
fiscal regime, Mariner is in similar depths, has oil with a similar API (11° at Heimdal and 14.5° at
Maureen), with similar gross reserves and is also operated by Statoil.
Exhibit 4: Nautical’s reserves relative to other North Sea peers
0
100
200
300
400
500
Pre
mie
r Oil
Dana P
etrole
um
Xcite
Energ
y
Northern
Petrole
um
Ste
rling
Resourc
es
Antrim
Energ
y
Endeavo
ur
Inte
rnatio
nal
Ithaca E
nerg
y
Seric
a E
nerg
y
Valia
nt
Petrole
um
Nautic
al
Petrole
um
Faro
e
Petrole
um
2P 2C=
Source: Last reported 2P and 2C reserves from company presentations
Core NAV of 326p/share
Exhibit 5: Valuation summary
FD shares (m) 69 .3
$ /£ 1.5
Netback
Assets Country/ WI Hydroc.
Licence % Fluid
Under development
Mariner UK 27% Oil 40% 369.0 90.3 5.8 209.2 201.4
Kraken UK 35% Oil 50% 83.1 29.1 7.8 107.9 103.8
TOT TOT 305
Cash/(Net Debt) 25 24.2
G&A (4 ) (4 )
Core NAV TOT 326
Explorat ion/Appraisa l
Catcher UK 15% Oil 30% 21.8 3.3 7.9 5.7 5.5
Grenade France 22% Gas 10% 4.2 0.9 7.6 -0.3 -0.3
Tudor Rose UK 20% Oil 36% 49.0 9.8 8.7 29.7 28.5
Merrow UK 50% Oil 15% 122.8 61.4 10.8 95.0 91.5
TOT 72.1 TOT 120
RENAV TOT 445
Unris ked
Reserves /Resources
CoS
Value/sh
(p)
EMV
$m
NPV/boe
($ /boe)
Net
mmboe
Gross
mmboe
=Source: Nautical Petroleum
Exhibit 5 summarises our valuation of Nautical’s assets. Geological risk factors are derived from a
consideration of the probabilities of the presence of reservoir, presence of a trap and presence of a
hydrocarbon system. Appraisal and development risk factors reflect the work needed to bring the
field into production.
Our standard key assumptions are as follows:
• We apply a 10% discount rate, combined with the conservative risk factors.
• We are currently using a forward oil price of $60/bbl.
• We include in our valuation exploration subject to near-term drilling.
• We apply an exchange rate of US$1.50/£.
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Based on this, Nautical’s current share price of 51p is significantly below its core NAV. The current
share price reflects disappointment over the last dry well, shareholder impatience and doubt over
the development of Mariner and concerns as to whether Nautical can finance development of both
Kraken and Mariner. Both these have the potential to be rectified, however, with the upcoming
Kraken drilling campaign and Statoil approaching DG2 on Mariner.
Financials: Capex spend to accelerate with drilling
Gross capex for bringing Kraken to production is expected to be around £315m, of which £44m is
expected to be incurred in 2011. With Nautical’s partner Canamens Energy North Sea not
participating in the drilling, Nautical will fund 70% of the initial dual penetration well. If successful,
Canamens has an option to buy back into the well by repaying Nautical 35% of the gross drilling
and testing costs within 30 days of the well result and then contributing a further 35% of the gross
well and testing costs during the development phase. In the event that Canamens chooses not to
participate in a successful find, Nautical would have an effective 70% working interest in the
additional oil proved up, although if this was the case, we believe the company would most likely
farm down a stake.
In addition, the company is likely to incur a further £5m of cost to bring Mariner from DG2 to FDP
approval in 2011.
This suggests that the company will have to secure funding to pursue bringing these fields on
stream. Nautical did state at its last results presentation that it expects to debt finance the majority
of the expenditure.
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Exhibit 6: Financials £'000s 2006 2007 2008 2009 2010e 2011e
Year end 30 June
PROFIT & LOSS
Revenue 0 0 0 25 70 70
Cost of Sales 0 0 0 (28) (92) (92)
Gross Profit 0 0 0 (3) (22) (22)
EBITDA (2,245) 144 (1,726) (1,094) (3,700) (5,000)
Operating Profit (before GW and except.) (2,316) 0 (1,868) (1,094) (3,700) (5,000)
Impairment of exploration assets (5,077) (1,430) (3,244) (6,507) 0 0
Exceptionals 0 0 0 0 0 0
Other 0 0 0 0 0 0
Operating Profit (7,393) (1,430) (5,112) (7,601) (3,700) (5,000)
Net Interest 210 567 592 965 10 (850)
Profit Before Tax (norm) (2,106) 567 (1,276) (129) (3,690) (5,850)
Profit Before Tax (FRS 3) (7,183) (863) (4,520) (6,636) (3,690) (5,850)
Tax 0 472 0 749 0 0
Profit After Tax (norm) (2,106) 1,039 (1,276) 620 (3,690) (5,850)
Profit After Tax (FRS3) (7,183) (391) (4,520) (5,887) (3,690) (5,850)
Average Number of Shares Outstanding (m) 46.0 53.8 60.6 63.4 63.4 63.4
EPS - normalised (p) (4.6) 2.1 (2.1) 1.0 (5.8) (9.2)
EPS - FRS 3 (p) (15.7) (0.5) (7.4) (9.3) (5.8) (9.2)
Gross Margin (%) N/A N/A N/A N/A N/A N/A
EBITDA Margin (%) N/A N/A N/A N/A N/A N/A
Operating Margin (before GW and except.) (%) N/A N/A N/A N/A N/A N/A
BALANCE SHEET
Fixed Assets 52,011 75,656 58,846 50,134 56,325 93,125
Intangible Assets 49,279 49,768 56,400 48,857 56,057 84,957
Tangible Assets 2,732 25,888 2,446 277 268 8,168
Investment in associates 0 0 0 1,000 0 0
Unquoted investments 0 0 0 0 0 0
Current Assets 13,033 9,233 20,722 19,634 9,814 7,014
Stocks 0 0 0 0 0 0
Debtors 733 290 604 573 643 643
Cash 12,300 8,943 20,118 19,061 9,171 6,371
Other 0 0 0 0 0 0
Current Liabilities (1,902) (1,386) (4,658) (809) (809) (809)
Creditors (823) (490) (4,658) (809) (809) (809)
Other creditors 0 0 0 0 0 0
Short term borrowings (1,079) (896) 0 0 0 0
Minority interests 0 0 0 0 0 0
Long Term Liabilities (11,218) (10,969) (9,455) (9,148) (9,148) (48,148)
Long term borrowings (360) 0 0 0 0 (39,000)
Other long term liabilities (10,858) (10,969) (9,455) (9,148) (9,148) (9,148)
Net Assets 51,924 72,534 65,455 59,811 56,182 51,182
CASH FLOW
Operating Cash Flow (1,380) (677) (1,684) (367) (3,700) (5,000)
Net Interest 302 493 622 684 10 0
Tax 0 0 0 0 0 0
Capex (2,401) (2,695) 0 (11,804) (7,200) (36,800)
Acquisitions/disposals (1,930) 0 (13,456) 11,938 0 0
Financing 17,055 0 19,162 0 0 0
Dividends 0 0 0 (508) 0 0
Other 0 0 4,390 0 0 0
Net Cash Flow 11,646 (2,879) 9,034 (57) (10,890) (41,800)
Opening net debt/(cash) (8) (10,861) (8,047) (20,118) (20,061) (9,171)
HP finance leases initiated 0 0 0 0 0 0
Other (793) 65 3,037 0 0 0
Closing net debt/(cash) (10,861) (8,047) (20,118) (20,061) (9,171) 32,629 ==
Source: Company accounts, Edison Investment Research
==12 | Edison Investment Research | Outlook | Nautical Petroleum | 2 June 2010
=
Growth Profitability Balance sheet strength Sensitivities evaluation
N/A N/A
-40
-30
-20
-10
0
10
20
30
2007 2008 2009 2010e 2011e
Net c
ash
(£'m
s)
Litigation/regulatory
Pensions
Currency
Stock overhang
Interest rates
Oil/commodity prices
Growth metrics % Profitability metrics % Balance sheet metrics Company details
EPS CAGR 07-11e N/A ROCE 10e N/A Gearing 10e N/A Address:
EPS CAGR 09-11e N/A Avg ROCE 07-11e N/A Interest cover 10e 370 Parnell House,
25 Wilton Road,
London, SW1V 1YD EBITDA CAGR 07-11e N/A ROE 10e N/A CA/CL 10e 12.1
EBITDA CAGR 09-11e N/A Gross margin 10e N/A Stock turn 10e N/A Phone 020 7550 4890
Sales CAGR 07-11e N/A Operating margin 10e N/A Debtor days 10e N/A Fax 020 7550 4816
Sales CAGR 09-11e N/A Gr mgn / Op mgn 10e N/A Creditor days 10e N/A www.nauticalpetroleum.com
Principal shareholders % Management team
International Energy Group AG 30.9 CEO: Steve Jenkins
MHR Advisors LLC 7.9 Mr Jenkins has spent 27 years in the oil and gas industry.
Having graduated with an MSc in Petroleum Geology from
Imperial College, he spent 11 years as business development
and HSE manager at Nimir Petroleum and has previous
experience of heavy oilfields from onshore Colombia and
Kazakhstan. He is currently chair of the Oil & Gas Independents
Association (OGIA), and a director of Oil & Gas UK.
Sin Cheon Co Ltd 6.0
Drawbridge Global Macro Master Fund 5.8
Commercial Director: Paul Jennings
Mr Jennings has over 30 years in the oil and gas sector in
roles covering accountant, economist and business
development. He worked with BP for 17 years with
responsibility for projects in China, Russia, Mongolia,
Mozambique and west Africa. After leaving BP he established
exploration and production companies in both Russia and
Nigeria, before jointly founding Nautical Petroleum with Steve
Jenkins.
Forthcoming announcements/catalysts Date *
Final results November FD: Will Mathers
Interim results March Mr Mathers spent six years as an accountant with Deloitte
specialising in the energy and mining sectors before joining
Woodside Petroleum, holding financial roles in the US and
Australia. Prior to joining Nautical, he was Global Office
Controller for Shell Gas (LPG) in London.
AGM December
Note: * = estimated
Companies mentioned in this report:
Antrim Energy, Canamens Energy, Dana Petroleum, Encore Oil, Endeavour International, Faroe Petroleum, Ithaca Energy, Northern Petroleum, Premier
Oil, Serica Energy, Statoil, Sterling Resources, Valiant Petroleum, Xcite Energy
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