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Trends in the Global Offshore Industry Marine Money China Ship Finance Conference 10th May 2017
Piers Middleton Managing Director H. Clarkson & Company Limited
Agenda
2
Introduction
The global rig market
Subsea
OSV & North Sea perspectives
3
The oil services market has bottomed
Source: Schlumberger; Bloomberg; Clarksons Platou Offshore
-
2 000
4 000
6 000
8 000
10 000
12 000
14 000
16 000
18 000
Q1 13 Q2 13 Q3 13 Q4 13 Q1 14 Q2 14 Q3 14 Q4 14 Q1 15 Q2 15 Q3 15 Q4 15 Q1 16 Q2 16 Q3 16 Q4 16
Schlumberger, Quarterly revenues, USDm «All markets have now reached the bottom, including Sub-Saharan
Africa and Asia”
Schlumberger CEO Paal Kibsgaard, 20 Jan-2017
Source: IEA; International Oil Daily; Bloomberg; Schlumberger; Clarksons Platou Offshore
4
What’s the shape of the recovery?
V V-shaped?
U U-shaped?
L L-shaped?
Bathtub-shaped?
“We look at 2017 as the starting point of a new multiyear cycle, where the main challenge is actually going to be to reverse the effect of
several years of global E&P underinvestment and then try to mitigate the pending supply
shortage that we see unfolding”
Schlumberger CEO Paal Kibsgaard, 20 Jan-2017
“We need USD 700bn of upstream investment each year” (compared to 2016 USD ~430bn,
IEA estimate)
IEA Executive Director Faith Birol, 30 Jan-2017
The oil market is rebalancing
5
Global oil demand and supply
Source: IEA; Clarksons Platou Offshore
86
88
90
92
94
96
98
100
86
88
90
92
94
96
98
100
Q112 Q1 13 Q1 14 Q1 15 Q1 16 Q1 17
Mbd
Mbd
Demand Supply
Expect tightening market in H1/17. H2/17 depends on Opec compliance, Russia and shale response
*) Est. with Opec at 32.8 mbd
Global oil demand is robust. Increasingly non-OECD driven
6
Source: BP Statistical Review of World Energy 2016; The World Bank; Clarksons Platou Offshore
Average demand growth 1965-present: 1.3 mbl/d p.a. The IEA recently revised 2015 and 2016 demand growth numbers to +2 mbl/d and +1.6 mbl/d respectively and now estimates average annual demand growth to 2022 of +1.2 mbl/d (+ 1.5 mbl/d for 2017)
-
10
20
30
40
50
60
70
80
90
100
0
10
20
30
40
50
60
70
80
90
100
1965 1967 1969 1971 1973 1975 1977 1979 1981 1983 1985 1987 1989 1991 1993 1995 1997 1999 2001 2003 2005 2007 2009 2011 2013 2015
Glo
bal G
DP (U
SD tr
n.)
Oil
dem
and
(mbl
/d)
Non-OECD oil demandOECD oil demandWorld GDP
1965: 31 mbl/d
3x
2015: 95 mbl/d
Conventional crude oil resources receiving approval worldwide
Source: IEA analysis based on Rystad Energy (from IEA WEO 2016 report, Nov-16); Clarksons Platou Offshore
This is not sustainable and everything points to a strong recovery, though timing remains uncertain
7
Sanctioning activity over the last couple of years: Dismal, and not enough to meet future demand growth and compensate for depletion
At 96 mbl/d, the world consumes 35
bn. barrels p.a.
270
150
0
50
100
150
200
250
300
2014 2016
NO
K bn
Development cost, selected NCS projects
Offshore is still relevant: ~27% of global oil supply, ~60% of Major’s production and ~55% of their 2P reserves
8
Relative cost compression vs. onshore also likely to have an impact forward
Offshore is ~27% of global oil supply
- 44%
Offshore is still vital for majors Offshore costs down substantially
58 % 53 % 48 %59 %
46 %
68 %
90 % 84 %
60 %
42 % 47 % 52 %41 %
54 %
32 %
10 % 16 %
40 %
0 %10 %20 %30 %40 %50 %60 %70 %80 %90 %
100 %
Shel
l
XOM
Chev
ron
Tota
l
BP ENI
Petr
obra
s
Stat
oil
Wei
ghte
d av
g.
2016 production shares
Offshore Onshore
Note 1: Oil production illustrated here represents crude oil and NGL production only. Refinery gains and other liquids (biofuels) excluded (hence, data deviate somewhat from e.g. IEA numbers) Note 2: NPD’s analysis is based on estimates from the operating companies for the following projects: Utgard, Oda, Zidane, Trestakk, Snilehorn, Johan Castberg, Snorre Expansion and Johan Sverdrup ph-2 Source: Clarksons Research Services (CRS); NPD (the Norwegian Petroleum Directorate), based on the operating companies’ own estimates; TechnipFMC; (WoodMack) Clarksons Platou Offshore
Offshore likely to increase relative competitiveness out of the trough as cost structure continues to compress relative to shale (Up to 50% of offshore costs are facilities/engineering, while well services dominate shale costs)
Global rig demand has been at record-low levels through 2015/16
9
JU-fixing at clear all-time low in our time series Floaters: 2016 proves to be another miserable year
Note: Other fixtures relate to Petrobras’ domestic newbuilds / SETE program (2011 & 2012) and NADL/Rosneft (2014) Source: Clarksons Platou Offshore
About 40 rig years fixed for JU’’s globally first two months of 2017 240 rig years at “run-rate”. Not enough, but at least another indication market conditions are about to improve somewhat
Number of working rigs coming down hard across the world
10
Floaters – Currently down to 135 contracted units, further decline is likely
• Latest actual demand in terms of floaters on contract (Dec-16) was 135 units
Source: Clarksons Platou Offshore
Jackups – Number of active working rigs keeps coming down faster than we had estimated
• Latest actual demand (Dec-16), measured by units on contract, was 290 units. This has flattened lately. Summer-16 saw 300 JU’s on contract on average
0
50
100
150
200
250
300
2000
2001
2002
2003
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015
2016
e
2017
e
2018
e
Floater demand: Actual and forecasted
Demand - actual and base case Forecasted fixing activity model
Rig spend model (volume effects) Backlog (no new fixtures)
0
50
100
150
200
250
300
350
400
450
500
2000
2001
2002
2003
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015
2016
e
2017
e
2018
e
Jackup demand: Actual and forecasted
Demand - actual and base case Rig spend model
Top down model (strip oil price) Bottom up model
Backlog (no new fixtures)
Currently 100-110 likely actually working
290 on contract as of Dec-16
Active fleet utilization is hovering around 70% for both the global floater and jackup fleet. Rates are largely around rig opex-levels, naturally with various nuances
Floater market: We need to go back to 2004 to see corresponding low floater demand (as measured by number of floaters on contract)
11
Source: IHS Petrodata; Clarksons Platou Offshore
-
50
100
150
200
250
300
1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10
86 87 88 89 90 91 92 93 94 95 96 97 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016
Floaters on contract, monthly since 1986
Updated September 2016. Source: IHS Petrodata; Clarksons Platou Sec.
12
Floaters: Dropping everywhere. Several regions likely to drop further during 2017 before leveling out and gradually increase again
35 3328
3641
48 47
3530
2009 2010 2011 2012 2013 2014 2015 2016 2017
US Gulf Of Mexico
4
3 3
4
5
65
4
3
2009 2010 2011 2012 2013 2014 2015 2016 2017
Mexico
50
61
74
8478
67
55
3934
2009 2010 2011 2012 2013 2014 2015 2016 2017
South America
37 36 38
44 46 4541
3227
2009 2010 2011 2012 2013 2014 2015 2016 2017
NW Europe
2926
31 3237
43
34
2218
2009 2010 2011 2012 2013 2014 2015 2016 2017
West Africa
1112 12
1416
15
9
6 7
2009 2010 2011 2012 2013 2014 2015 2016 2017
Indian Ocean
11
1517
15
13
16
119
7
2009 2010 2011 2012 2013 2014 2015 2016 2017
SE Asia
11 1110 10 10
11
9
4 4
2009 2011 2013 2015 2017
Australia/New Zealand
Jackups: 290 units on contract, same level as last trough in 2009 (293). Prior to that, need to go to 2002/03 to see corresponding low number
13
0
50
100
150
200
250
300
350
400
450
1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10 1 4 7 10
86 87 88 89 90 91 92 93 94 95 96 97 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 Source: IHS Petrodata; Clarksons Platou Offshore
Jackups on contract, monthly since 1986
15
1921
23 24
20
17
10
6
2009 2010 2011 2012 2013 2014 2015 2016 2017
US Gulf Of Mexico
32
25 2632
42
52
44
29 26
2009 2010 2011 2012 2013 2014 2015 2016 2017
Mexico
1110 10
8 89
7
54
2009 2010 2011 2012 2013 2014 2015 2016 2017
South America
30 3236
41 4247 46
36
28
2009 2010 2011 2012 2013 2014 2015 2016 2017
NW Europe
15
1921
23 24
20
17
10
6
2009 2010 2011 2012 2013 2014 2015 2016 2017
West Africa
84 89 94105
120129 130
123112
2009 2010 2011 2012 2013 2014 2015 2016 2017
Middle East
3330 31 29
32 32 3236
40
2009 2010 2011 2012 2013 2014 2015 2016 2017
Indian Ocean
37 40
49
57
65 66
50
30 27
2009 2010 2011 2012 2013 2014 2015 2016 2017
SE Asia
4
11
2 2
1
21 1
2009 2011 2013 2015 2017
Australia/New Zealand
Updated September 2016. Source: IHS Petrodata; Clarksons Platou Sec.
14
Jack-up overview: Middle East & Indian Ocean stable/increasing. W.Afr set to increase? Mexico and SE Asia stabilizing, set to increase forward?
Source: IHS Petrodata; Clarksons Platou Offshore
15
Jackup rigcount (rigs on contract) has started flattening
Jackups – Number of active working rigs (on contract), monthly since 2012 – flattening out last 3-5 months
200
250
300
350
400
450
1 3 5 7 9 11 1 3 5 7 9 11 1 3 5 7 9 11 1 3 5 7 9 11 1 3 5 7 9 11
2012 2013 2014 2015 2016
Jackups on contract, monthly
Comments
• More than 50% of the contracted JU’s are in the Middle East and Indian Ocean – regions that have seen stable/increasing demand and continue to do so
• Several other regions have seen JU-count drop ~50% from peak. Further drop unlikely
• Majority of JU-drilling is development and re-development/intervention = stable
• Also, quite a bit of the JU’s are used for gas fields = usually more stable than oil
• Oil price +50% since trough will lead oil companies to increase short lead-time investments again = use more JUs
• We are seeing positive market indications (RFIs etc.)
Subsea displays signals of bottoming out. Backlogs will start to build again as oil companies increase sanctioning activity, likely late-17
16
0
1000
2000
3000
4000
5000
6000
Q1/
07
Q3/
07
Q1/
08
Q3/
08
Q1/
09
Q3/
09
Q1/
10
Q3/
10
Q1/
11
Q3/
11
Q1/
12
Q3/
12
Q1/
13
Q3/
13
Q1/
14
Q3/
14
Q1/
15
Q3/
15
Q1/
16
Q3/
16
Cameron (OneSubsea) subsea backlog (USDm)
0
5
10
15
20
25
30
35
40
45
Q1/
07
Q3/
07
Q1/
08
Q3/
08
Q1/
09
Q3/
09
Q1/
10
Q3/
10
Q1/
11
Q3/
11
Q1/
12
Q3/
12
Q1/
13
Q3/
13
Q1/
14
Q3/
14
Q1/
15
Q3/
15
Q1/
16
Q3/
16
Subsea EPC (SUBC + TEC Subsea + SPM E&C Offshore) backlog, USDbn
Leading Subsea equipment manufacturer backlog stabilizing last 3-4 quarters…
…and the same is visible in the combined backlog for the world’s three leading Subsea contractors
Source: Subsea 7; Technip; Saipem; FMC Technologies; Interntional Oil Daily; Clarksons Platou Offshore
Global Subsea fleet utilization is currently below 50% and subsea vessel operators are experiencing significant pressure
Subsea construction outlook: Tree awards estimated to bottom out in 2016, pipe installations in 2018. Strong installation/construction rebound 2019+
17
Quest X-mas tree awards outlook scenarios: Tree awards estimated to bottom out in 2016
Subsea pipeline installations to remain low 2016-18 with 2018 being the trough year
• Strong recovery in 2018+ naturally dependent on continued oil price recovery
• FPU awards display same picture as equipment awards ―Three awards in 2015, zero in 2016. YTD-17, we have seen two firm awards, full-year likely to end at 5-6 ―FPU construction/conversion takes 2-3Y installation offshore in 2019/20
Source: Quest Offshore; Clarksons Platou Offshore
-
1 000
2 000
3 000
4 000
5 000
6 000
2008 2009 2010 2011 2012 2013 2014 2015 2016e 2017e 2018e 2019e 2020e 2021e
Global - pipeline demand (km)
0-14 Rigid Steel 15-19 Rigid Steel 20-24 Rigid Steel 25+ Rigid Steel Flexible
0
100
200
300
400
500
600
700
# of
Sub
sea
Tree
s
Award Year
Tree Orders (High) Tree Orders (Mean) Tree Orders (Base)
30%+ of the global OSV fleet is now stacked…
18
Global lay-ups, current status according to our data Stacking development globally, AHTS and PSVs
Source: Clarksons Research Services; Clarksons Platou Offshore
Total ~1650 vessels, in excess of 30% of the fleet
0
200
400
600
800
1,000
1,200
1,400
1,600
1,800
2,000
2008
-Jan
2008
-Jul
2009
-Jan
2009
-Jul
2010
-Jan
2010
-Jul
2011
-Jan
2011
-Jul
2012
-Jan
2012
-Jul
2013
-Jan
2013
-Jul
2014
-Jan
2014
-Jul
2015
-Jan
2015
-Jul
2016
-Jan
2016
-Jul
2017
-Jan
PSV
AHTS
Proper data capture is challenging in the OSV-segment, but nevertheless, other sources seem roughly in line with our data
19
Graphs and data from recent IHS Petrodata presentation
Total 1500+ vessels…
…corresponding to ~40% of the fleet
Source: IHS Petrodata; Clarksons Platou Offshore
Global OSV utilisation overview
AHTS PSV
20
Source: IHS Petrodata; Clarksons Platou Offshore
0%
10%
20%
30%
40%
50%
60%
70%
80%
0
100
200
300
400
500
600
Jan
2011
Jun
2011
Nov
201
1
Apr 2
012
Sep
2012
Feb
2013
Jul 2
013
Dec
2013
May
201
4
Oct
201
4
Mar
201
5
Aug
2015
Jan
2016
Jun
2016
Nov
201
6
AHTS 10-000+ BHP
Working Term Spot Market
Not Working Out of Market Work
Term Utilisation
0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
0
200
400
600
800
1000
1200
1400
Jan
2011
Jun
2011
Nov
201
1
Apr 2
012
Sep
2012
Feb
2013
Jul 2
013
Dec
2013
May
201
4
Oct
201
4
Mar
201
5
Aug
2015
Jan
2016
Jun
2016
Nov
201
6
PSV 2000+ DWT
Working Term Spot Market
Not Working Out of Market Work
Term Utilisation
OSV term rates are at or close to opex levels. Likely to remain low as long as overcapacity persists
Source: Clarksons Platou Offshore
0
10
20
30
40
50
60
0
10
20
30
40
50
60
05 06 07 08 09 10 11 12 13 14 15 16 17
USD
'000
USD
'000
North Sea PSV average term rates
500-749 m2 2,200 - 3,099 dwt 750-899 m23,100+ dwt 900+ m2
0
5
10
15
20
25
30
35
40
0
5
10
15
20
25
30
35
40
05 06 07 08 09 10 11 12 13 14 15 16 17
USD
'000
USD
'000
Brazil PSV average term rates
500-750 m2 900+ m2
0
5
10
15
20
25
30
35
40
0
5
10
15
20
25
30
35
40
05 06 07 08 09 10 11 12 13 14 15 16 17
USD
'000
USD
'000
West Africa PSV average term rates
500-749m2 900+ m2
0
5
10
15
20
25
30
35
40
45
0
5
10
15
20
25
30
35
40
45
05 06 07 08 09 10 11 12 13 14 15 16 17
USD
'000
USD
'000
US Gulf PSV average term rates
500-749 m2 750-899 m2 900+ m2
Source: Clarksons Platou Offshore
22
AHTS term rates are at or close to opex levels. Likely to remain low as long as overcapacity persists
0
10
20
30
40
50
60
70
0
10
20
30
40
50
60
70
05 06 07 08 09 10 11 12 13 14 15 16 17
USD
'000
USD
'000
North Sea AHTS average term rates
10-15,999 BHP 16-19,999 BHP 20,000+ BHP
0
5
10
15
20
25
30
35
40
45
50
0
5
10
15
20
25
30
35
40
45
50
05 06 07 08 09 10 11 12 13 14 15 16 17
USD
'000
USD
'000
West Africa AHTS term rates
5,000 BHP 10,000 BHP 12,000 BHP 16,000 BHP
0
10
20
30
40
50
60
70
0
10
20
30
40
50
60
70
05 06 07 08 09 10 11 12 13 14 15 16 17
USD
'000
USD
'000
Brazil AHTS average term rates
7,000 BHP 12,000 BHP 15,000 BHP 18,000 BHP 21,000 BHP
0
5
10
15
20
25
30
35
40
45
50
0
5
10
15
20
25
30
35
40
45
50
05 06 07 08 09 10 11 12 13 14 15 16 17
USD
'000
USD
'000
South-East Asia AHTS average term rates
5,000 BHP 7,000 BHP 8,000 BHP 10,000 BHP 12,000 BHP
North Sea spot rates are bottoming out
AHTS PSV
23
Source: Clarksons Platou Offshore
0
5
10
15
20
25
30
35
40
45
50
55
60
65
70
75
80
2008 2009 2010 2011 2012 2013 2014 2015 2016 2017
GBP '000
10-15,999 BHP 16-19,999 BHP 20,000+ BHP
0
2.5
5
7.5
10
12.5
15
17.5
20
22.5
25
2008 2009 2010 2011 2012 2013 2014 2015 2016 2017
GBP '000
500-899 m2 900+ m2
Time to consolidate…
24
1999: Worldwide, PSVs > 2,000 DWT (top) and AHTS > 10,000 BHP
Source: Farstad Shipping – Presentation at Pareto conference Sept-99 and Q2/16-presentation; Clarksons Platou Offshore
2016: PSVs > 2,000 DWT and AHTS > 10,000 BHP
Rebalancing? Provided significant vessel attrition, the OSV market could be back in reasonable balance in 2020 (modeled scenario from CP Securities)
25
87 % 88 % 88 % 90 % 91 % 92 % 94 % 94 %91 %
86 % 86 % 88 % 88 %86 %
77 %
66 % 65 %
71 %
80 %
85 %
0 %
10 %
20 %
30 %
40 %
50 %
60 %
70 %
80 %
90 %
100 %
0
500
1 000
1 500
2 000
2 500
3 000
3 500
2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016E 2017E 2018E 2019E 2020E
OSV
flee
t util
izatio
n
# of
ves
sels
OSV supply, demand and fleet utilization - 2001 to 2020E
Production support demand Rig demand Total supply Adjusted supply Adjusted utilization
Source: Clarksons Platou Offshore
Note that there are multiple moving parts and numerous assumptions made to attempt to analyze the market-balance in the OSV market. Estimates and timing thus remain highly uncertain
Some other interesting aspects starting to play out in the OSV space, constituting big question marks…
26
Charterer: “We are not going to take stacked boats”
Owner: “We are not going to take boats out of lay up unless at least 6 months charter and compensated”
Everyone: “What’s going to happen to all these stacked boats? How fast will they deteriorate?”
Broker: “How many of these large stacked PSVs have their 5Y SPS coming up during next 1-2 years?”
“What is the viability of the traditional owners’ operating model in a world where Standard/Fletcher Shipping type of companies increasingly operate vessels?”
? Everyone: “How large percentage of the order book will eventually hit the market?”
Charterer: “I’m not willing to look at anything which is less than 3Y at opex”
Charterer: “At the current pace, all these established owners are going out of business, and that’s bad for me! I rely on these companies”
• The oil services market has bottomed out
• There is a future for Offshore
• Shape and pace of the recovery still uncertain
• Activity is starting to pick up (seismic late-sales, jackup tendering ++)
• All asset-heavy segments (Rig, OSV, Subsea) hampered by significant overcapacity ― Utilization and dayrates will take long to recover ― Substantial attrition needed. If carried out, segments can be rebalanced by 2020 ― We will still see a lot of restructuring, refinancing and consolidation
• Now and the coming 12-24 months likely good time to act on asset transactions for
those aiming to build a solid longer term position
27
Summary and conclusions
Important Information The material and the information (including, without limitation, any future rates) contained herein (together, the "Information") are provided by Clarksons Platou AS ("Clarksons Platou") for general information purposes. The Information is based solely on publicly available information and is drawn from Clarksons Platou's database and other sources. Clarksons Platou advises that: (i) any Information extracted from Clarksons Platou's database is derived from estimates or subjective judgments; (ii) any Information extracted from the databases or information services of other maritime data collection agencies may differ from the Information extracted from Clarksons Platous' database; (iii ) whilst Clarksons Platou has taken reasonable care in the compilation of the Information and believes it to be accurate and correct, data compilation is subject to limited audit and validation procedures and may accordingly contain errors; (iv) the provision of the Information does not obviate any need to make appropriate further enquiries; (v) the provision of the Information is not an endorsement of any commercial policies and/or any conclusions by Clarksons Platou and its 'connected persons', and is not intended to recommend any decision by the recipient; (vi) shipping is a variable and cyclical business and any forecasting concerning it may not be accurate. The Information is provided on "as is" and “as available” basis. Clarksons Platou and its ‘connected persons’ make no representations or warranties of any kind, express or implied about the completeness, accuracy, reliability, suitability or availability with respect to the Information. Any reliance placed on such Information is therefore strictly at the recipient's own risk. The opinions and estimates contained herein represent the view and judgment as of the dates specified (and in absence of such, as of the date of the report), and are subject to change without notice. Delivery of this report shall not create any implication that Clarksons Platou assumes any obligation to update or correct the Information. This Information is confidential and is solely for the internal use of the recipient. Neither the whole nor any part of the Information may be disclosed to, or used or relied upon by, any other person or used for any other purpose without the prior written consent of Clarksons Platou. Especially, the information is not to be used in any document for the purposes of raising finance whether by way of debt or equity. All intellectual property rights are fully reserved by Clarksons Platou, its ‘connected persons’ and/or its licensors. To the extent permitted by law, Clarksons Platou and its ‘connected persons’ shall not be liable to the recipient or any third party for any loss, liability or damage, cost or expense including without limitation, direct, indirect, consequential loss or damage, any loss of profit, loss of use, loss of or interruption in business, loss of goodwill, loss of data arising out of, or in connection with, the use of and the reliance on the Information whether in contract, tort, negligence, bailment, breach of statutory duty or otherwise, even if foreseeable. These exclusions do not apply to the liability of Clarksons Platou and its ‘connected persons’ for fraud or fraudulent misrepresentation. In this disclaimer 'connected persons' means, in relation to Clarksons Platou, its ultimate holding company, subsidiaries and subsidiary undertakings of its ultimate holding company and the respective shareholders, directors, officers, employees and agents of each of them. This disclaimer shall be governed by and construed in accordance with Norwegian law. H. CLARKSON & CO. LTD, COMMODITY QUAY, ST. KATHARINE DOCKS, LONDON, E1W 1BF
28
Disclaimer
Clarksons Platou Offshore Commodity Quay
St Katharine Docks. London Switchboard telephone: +44 207 334 3138
www.clarksons.com