kca deutag q1 2014 investor presentation...first quarter 2014 investor presentation disclaimer 1 the...
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www.kcadeutag.com
KCA Deutag is a leading international drilling and engineering
company working onshore and offshore with a focus on safety,
quality and operational performance
First Quarter 2014
Investor Presentation
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Disclaimer
1
The distribution of this presentation in certain jurisdictions may be restricted by law. Persons into whose possession this presentation comes are required to inform themselves about and to observe any such restrictions.
This presentation contains forward-looking statements concerning KCA Deutag. These forward-looking statements are based on management’s current expectations, estimates and projections. They are subject to a number of assumptions and involve known and unknown risks, uncertainties and other factors that may cause actual results and developments to differ materially from any future results and developments expressed or implied by such forward-looking statements. KCA DEUTAG has no obligation to periodically update or release any revisions to the forward-looking statements contained in this presentation to reflect events or circumstances after the date of this presentation.
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2
Agenda
1 Key Highlights
2 Commercial Developments
3 Business Overview
4 Group Results
5 Summary
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3
Q1 Key highlights
KCA Deutag is a leading international drilling and engineering company working onshore and offshore with a focus on safety, quality and operational performance
1Group revenue and EBITDA of $513.9m (Q1 2013: $474.7m) and $80.8m (Q1 2013: $56.2m) respectively
2Improved operational and financial performance from Land Drilling, RDS, Platforms and MODUs
3Successful refinancing has pushed our earliest significant maturities out to 2018
4Contract backlog of $8.5bn (as at 1 May 2014) across a blue chip customer base
5Net debt/LTM EBITDA leverage fell from 4.0x at Q4 2013 to 3.41x by Q1 2014
1Pro-forma Q1 2014. See slide 17 for full details.
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Integrated Land Drilling Offshore Drilling Services & Design
US$181m EBITDA (54% of total)¹ US$154m EBITDA (46% of total)¹
Land Drilling Bentec Platform Services Rig Design Services (RDS)
• Leading international premium drilling rig owner and operator
• Design and manufacture of high-end premium land rigs and components
• Leading global platform service operator outside North America
• Rig design engineering from concept to commission
• Operations: Russia, Africa, Middle East, Europe and SE Asia
• Facilities: Germany, Russia, Oman
• Operations: UK North Sea, Norway, Azerbaijan, Russia, SE Asia and Africa
• Offices: Aberdeen, Baku, Bergen, Houston, London
Market-leading international drilling & engineering company
4
Design &
Engineering
Design &
ManufactureOwn & OperateOwn & Operate ManageManage
• Rigs: High end fleet of 53 drilling rigs, 4 workover rigs
• 94% of new rigs since 2007 have been built by Bentec
• Facilities: Capacity for 12-16 rigs and 50 top drives2 p.a.
• Staff: c.3,050 managing drilling operations on 39 platforms
• Approx. 60% ofplatforms designed or refurbished by RDS
• Staff: c.850 engineers and support staff
¹ LTM BITDA pre-exceptional items, excluding MODUs and prior to allocation of central overheads. EBITDA by segment for 2013 has been re-presented to reallocate support costs which were previously shown as central overheads (such as HR, Supply Chain and IT costs) to the operational business segments. 2014 figures are presented on the same basis.2 High-specification mechanical equipment turning the drill string.
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Europe (inc North
Sea)23%
Russia20%
Africa14%
Caspian 13%
Middle East 11%
SE Asia10%
Other9%
Houston
Ben Loyaljack-up rig
Baku
London
Stavanger
Bad Bentheim
Tyumen
Nizwa
Ben Rinnesjack-up rig
St. Johns
Bergen
Dubai
Land Drilling Platform Services RDS offices MODUs BentecRegional offices
Continued strong market position and balanced portfolio of assets across highly attractive international markets
Aberdeen (HQ)
51EBITDA excludes results from the Ben Avon jack-up which was disposed of in March 2013 and is stated before normalisation adjustments and excluding central overheads of $53m.Map excludes work over land rigs, defined as being below 900HP.
PRESENCE IN KEY AREAS
2013 EBITDA split by region
North Sea /Norway25 Plat.
Europe & Caspian8 Rigs
Azerbaijan7 Plat.
Russia15 Rigs
Middle East
12 Rigs
Angola3 Plat.
Africa17 Rigs
Sakhalin3 Plat.
Brunei 1 Rig
Myanmar 1 Plat.
126
55 5040
15
0
30
60
90
120
150
Europe NorthAfrica
MiddleEast
North Sea Russia
Ye
ars
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0.0
0.2
0.4
0.6
0.8
1.0
1.2
1.4
1.6
Jan-04 Jan-05 Jan-06 Jan-07 Jan-08 Jan-09 Jan-10 Jan-11 Jan-12 Jan-13 Jan-14 Jan-15
TR
IR p
er
200,0
00 m
an
ho
urs
Total Recordable Incident Rate Improvement (TRIR)
TRIR (average)
6
Health, safety and environmental performance
Mar -14
KCAD TRIR at end Q1 2014 was 0.501 injuries per 200,000 man hours worked
IADC industry average 0.812 for 2013
1 Total Recordable Incident Rate per 200,000 man hours. This is a rolling 12 month average.2 KCAD Total Recordable Incident Rate is directly comparable with IADC’s Total Recordables (RCRD) statistic. IADC figures are annual and are not released until after year end, therefore no 2014 information is available.Note: IADC stands for International Association of Drilling Contractors.
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Significant new contracts – Platforms, Canada
7
Contract natureDrilling operations and maintenances services on the Hebron platform in Canada
Contract length & timeframes
12 years fixed (3 years pre-operations, 9 years operations and maintenance) with option to extend
Customer ExxonMobil
Contract value Multi-million dollar
“The award of our first contract in Canada by ExxonMobil Canada Properties is an excellent result. We look forward to continuing to develop a strong working relationship as we work on this project together.”Rune Lorentzen, President of Offshore, KCA Deutag
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8
Healthy backlog providing high level earnings visibility for the future
$1,258 $839$1,595
$3,692$51 $141
$4,015
$4,207
0
2,000
4,000
6,000
8,000
10,000
2014 2015 2016 and thereafter Total backlog$m
Contract Option
$980m $5,610m $7,899m$1,310m
$1,726m
$251m
$5,737m
$173m
$12m
Land Drilling
Bentec
Platforms
RDS
MODUs
Total contract backlog as at 1 March 20141
Contract backlog by BU as at 1 March 20141
Total contract backlog as at 1 May 2014
Contract backlog by BU as at 1 May 2014
$1,635
$273
$6,370
$144
$55
Land Drilling
Bentec
Platforms
RDS
MODUs
$1,072 $895$1,885
$3,852$54 $127
$4,445
$4,626
0
2,000
4,000
6,000
8,000
10,000
May to Dec 2014 2015 2016 and thereafter Total backlog$m
Contract Option
$1,126m $1,022m $6,330m $8,478m
1As presented in Q4 2013 pack.
Mar to Dec 2014
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Q1 2014
Q1 2013
Variance2014 YTD
2013 YTD
Variance
$m $m $m % $m $m $m %
Revenue 168.0 150.5 17.5 11.6 168.0 150.5 17.5 11.6
EBITDA pre support costs allocation1 38.5 30.3 8.2 27.1 38.5 30.3 8.2 27.1
Support costs allocation (2.8) (2.4) (2.8) (2.4)
EBITDA post support costs allocation1 35.7 27.9 7.8 28.0 35.7 27.9 7.8 28.0
Margin % 21.3 18.5 21.3 18.5
9
• Strong Q1 2014 performance with utilisation of 81% for the quarter (80% in Q1 2013)
• Improved utilisation and cost savings from the business efficiency programme have contributed to improving EBITDA in Europe versus Q1 2013 and Q4 2013
• Africa also saw improvement versus Q1 and Q4 2013 with two new rigs delivered in Algeria in mid 2013 contributing to the year on year uplift in EBITDA
• Russia results softened for the quarter due to a seasonal downturn in CDS activity and a rig moving between clients
Financial Performance to 31 March 2014
Land Drilling
1 EBITDA by segment for 2013 has been re-presented to reallocate support costs which were previously shown as central overheads (such as HR, Supply Chain and IT costs) to the operational business segments. 2014 figures are presented on the same basis.
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Q1 2014
Q1 2013
Variance2014 YTD
2013 YTD
Variance
$m $m $m % $m $m $m %
Revenue 26.3 40.9 (14.6) (35.7) 26.3 40.9 (14.6) (35.7)
EBITDA pre support costs allocation1 0.8 3.3 (2.5) (75.8) 0.8 3.3 (2.5) (75.8)
Support costs allocation (0.7) (0.8) (0.7) (0.8)
EBITDA post support costs allocation1 0.1 2.5 (2.4) (96.0) 0.1 2.5 (2.4) (96.0)
Margin % 0.4 6.1 0.4 6.1
Bentec
10
• Q1 2014 saw a significant reduction in revenue and EBITDA compared to the same period in 2013 and Q4 2013
• This is simply due to the manufacturing completion status of current rig orders and timing of component sales
• The order backlog is strong and higher EBITDA is expected later in the year, particularly in the second half
• During Q4 2013 we announced Bentec’s biggest ever contract award for 7 desert rigs for Enafor, Algeria
• Order intake on top drives has also been strong during Q1 2014
Financial Performance to 31 March 2014
1 EBITDA by segment for 2013 has been re-presented to reallocate support costs which were previously shown as central overheads (such as HR, Supply Chain and IT costs) to the operational business segments. 2014 figures are presented on the same basis.
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Platform Services
11
Financial Performance to 31 March 2014
1 EBITDA by segment for 2013 has been re-presented to reallocate support costs which were previously shown as central overheads (such as HR, Supply Chain and IT costs) to the operational business segments. 2014 figures are presented on the same basis.
Q1 2014
Q1 2013
Variance2014 YTD
2013 YTD
Variance
$m $m $m % $m $m $m %
Revenue 188.7 169.5 19.2 11.3 188.7 169.5 19.2 11.3
EBITDA pre support costs allocation1 25.1 19.7 5.4 27.4 25.1 19.7 5.4 27.4
Support costs allocation (1.9) (1.6) (1.9) (1.6)
EBITDA post support costs allocation1 23.2 18.1 5.1 28.2 23.2 18.1 5.1 28.2
Margin % 12.3 10.7 12.3 10.7
• New contract awards during 2013 in Angola and the Far East contributed to strong EBITDA growth from the same quarter 2013 (28.2%)
• High activity levels in Azerbaijan and Angola were also a contributing factor, while activity levels in Sakhalin remained stable
• UK EBITDA steady compared to Q1 2013 despite higher revenue, due to an increase in lower margin reimbursables
• Norway revenue and EBITDA reduced on the same period last year due to lower activity in the pipe rental business, lower reimbursables and the stacking of the Ringhorne platform
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RDS
12
• []
Financial Performance to 31 March 2014
• Continued extremely strong performance from the RDS business with EBITDA growth of 66.7% on Q1 2013
• Work on a number of large projects from 2013, such as Hebron in Canada and Statoil Mariner in the UK North Sea, has continued but will reduce in coming quarters as they reach completion
• Recent new awards maintain a healthy backlog
1 EBITDA by segment for 2013 has been re-presented to reallocate support costs which were previously shown as central overheads (such as HR, Supply Chain and IT costs) to the operational business segments. 2014 figures are presented on the same basis.
Q1 2014
Q1 2013
Variance2014 YTD
2013 YTD
Variance
$m $m $m % $m $m $m %
Revenue 96.0 81.4 14.6 17.9 96.0 81.4 14.6 17.9
EBITDA pre support costs allocation1 17.7 10.8 6.9 63.9 17.7 10.8 6.9 63.9
Support costs allocation (0.7) (0.6) (0.7) (0.6)
EBITDA post support costs allocation1 17.0 10.2 6.8 66.7 17.0 10.2 6.8 66.7
Margin % 17.7 12.5 17.7 12.5
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MODUs
13
• The two jackups (Ben Rinnes and Ben Loyal) contributed $5.6m EBITDA 2 in the quarter versus $4.5m in Q1 2013
• New contracts have now been signed for both jackups commencing May 2014
• The Ben Avon jack up, which was disposed of in March 2013, incurred a loss of $3.5m in Q1 2013
• The three barges (Glen Esk, Glen Tanar and Glen Affric) were profitable in Q1 2014 at $6.5m EBITDA2 compared to $1.2m in Q1 20132
Financial Performance to 31 March 2014
1EBITDA by segment for 2013 has been re-presented to reallocate support costs which were previously shown as central overheads (such as HR, Supply Chain and IT costs) to the operational business segments. 2014 figures are presented on the same basis.2Post reallocation of support costs.3Excluding the results of the barges and the Ben Avon, Q1 2014 EBITDA would be $5.6m and Q1 2013 would be $4.5m.
Q1 2014
Q1 2013
Variance2014 YTD
2013 YTD
Variance
$m $m $m % $m $m $m %
Revenue 40.7 39.3 1.4 3.6 40.7 39.3 1.4 3.6
EBITDA pre support costs allocation1 12.6 2.6 10.0 382.4 12.6 2.6 10.0 382.4
Support costs allocation (0.5) (0.4) (0.5) (0.4)
EBITDA3
post support costs allocation1 12.1 2.2 9.9 447.0 12.1 2.2 9.9 447.0
Margin % 29.7 5.6 29.7 5.6
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Group ResultsFinancial Performance to 31 March 2014
14
Revenue and EBITDA ($m) Q1 2014
Q1 2013
2014 YTD
2013YTD
Revenue from business units 520 483 520 483
Consolidation adjustments (6) (8) (6) (8)
Total revenue 514 475 514 475
EBITDA from business units 88 61 88 61
Corporate costs/other (7) (5) (7) (5)
Total EBITDA 81 56 81 56
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Cash Flow and Working CapitalFinancial Performance to 31 March 2014
15
Working Capital
9
(60)
*Deltas denote working capital movements from Q4 2013 and Q4 2012 respectively.
Free Cash Flow
9
• Main driver for stronger operating cash flow was the improvement in working capital (see right) and higher EBITDA
• Cash flow from investing activities includes capital expenditure and cash interest payments:
- Reduced levels of capital expenditure offset by:- Disposal proceeds from the sale of the Ben Avon jack up rig
in Q1 2013- Slightly lower interest payments in Q1 2014
• Reduction in working capital in Q1 2014.
• Higher receivables due to increased activity were offset by $22m early collection in Q1 2014 for the 4th rig for a customer in Algeria
• Increase in payables due to advance payments received for rigs to be manufactured by Bentec and then operated by the Land business unit
• Offset by higher work in process in Bentec associated with new build rig orders received at the end of 2013
15
(92)
(60.0)
(50.0)
(40.0)
(30.0)
(20.0)
(10.0)
-
10.0Q1 2014 Delta* Q1 2013 Delta*
Cash
Im
pact
of
Delt
a (
$m
)
Working Capital Delta
Working Capital Delta
Q1 2014
Q1 2013
2014 YTD
2013 YTD
Cash flow from operating activities
82 (46) 82 (46)
Cash flow from investing activities
(21) 2 (21) 2
Equity injection 0 40 0 40
Foreign exchange (1) 4 (1) 4
Net Cash flow before debt repayment
60 0 60 0
Drawdown/(repayment) of debt (net issuance costs)
(2) (12) (2) (12)
Net cash flow 58 (12) 58 (12)
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61
649
32 155
50
500
50
2014 Mar-15 Mar-16 Jun-16 Mar-17 2018 2019 2020 2021
Off B/S Guarantee Facility
Senior Secured Notes
$50m Additional RCF approved in A&E
Liquidity Facilities
Term Loans 255
93
16
Capital StructurePre and post refinancing
New maturity profile ($m)
250
500
375 375
2014 Mar-15 Mar-16 Jun-16 Mar-17 2018 2019 2020 2021
New Senior Secured Notes
TLB
Existing Senior Secured Notes
Liquidity facilities
Previous maturity profile ($m)
38
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17
Pro-forma EBITDA and Net Debt
Pro-forma net debt
Pro-forma EBITDA
$m
Q1 2014 LTM EBITDA 325.4
Exclusion of loss on the Barges1 1.2
Exclusion of Ben Avon2 (0.2)
Pro-forma new land rigs3 2.8
Algerian rigs lease charge added back4 3.8
Pro-forma Q1 2014 LTM EBITDA 333.0
Facility Q1 2014Actual
Sale of SET rigs1
Refinancing Pro-forma
Cash (65) (50) (20) (135)
Capex facility 29 (29) -
TLB 151 (151) -
TLC 530 (530) -
New WCF ($250m) - -
New Term Loan B & SSN - 750 750
Existing SSN 500 500
Other 24 24
Total debt 1,169 (50) 20 1,139
• Q1 2014 EBITDA and net debt have been calculated on a pro-forma basis for use in leverage calculations on the following slide
• This slide provides a reconciliation to group results
1Barges sale assumed in Q2 2014.2Ben Avon jackup disposed of in March 2013, therefore results have been excluded.3New land rigs in 2013 annualised. 4Exclusion of lease charge payable on 2 Algerian rigs which were moved into KCA Deutag financial group in January 2014.
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5x 4.8x
4x
3.4x
-
0.50
1.00
1.50
2.00
2.50
3.00
3.50
4.00
4.50
5.00
-
200
400
600
800
1,000
1,200
1,400
Q2 2013 Q3 2013 Q4 2013 Q1 2014Pro-forma
Net
deb
t an
d E
BIT
DA
($m
)
Net Debt
LTM EBITDA
Net debt/LTMEBITDA
-135
-67
500
500
2
2
24
24 180 530
375 375
-200 0 200 400 600 800 1000 1200 1400
Cash
Senior secured notes 2018
Liquidity facilities
Other
TLB & Capex facility
TLC
New TLB
Senior secured notes 2021
Net Debt Pre and Post Refinancing As at 31 March 2014
18
Net Debt 31 March 2014 – Pre refinancing
Net Debt 31 March 2014 – Pro-forma2 post refinancing
• Refinancing successfully completed 13 May 2014
• Existing Term Loan C, Term Loan B, Capex and Working Capital facilities repaid
• New $375 million new Term Loan B and $375 million 2021 Senior Notes drawn
Net debt / LTM EBITDA
1Net debt portrayed as a positive figure to simplify illustration.2See preceding slide for full reconciliation to group results.
Net debt1
$1,169m
$1,139m
2
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Closing remarks
19
���� • Continued strong performance in Q1 2014 provides an excellent foundation for 2014 and beyond
���� • Excellent backlog of $8.5bn underpins future earnings
���� • Important contract wins with more in the pipeline
���� • Successful refinancing means no significant debt maturities until 2018
���� • Actions continue to optimise the business portfolio and increase business efficiency in 2014
����• Growth opportunities are only being pursued where they provide robust capex returns driving
increased cash generation based upon long term contracts
����• All of this is underpinned by a stable and experienced management team focused on further
delivery of results