MRO Magazine

Technip’s Second Quarter 2015 Results


July 30, 2015
By Business Wire News

PARIS

Regulatory News:

Technip (Paris:TEC) (ISIN:FR0000131708) (ADR:TKPPY):

On July 28, 2015, Technip’s Board of Directors approved the second quarter and first half 2015 adjusted consolidated financial statements.

Note: The second quarter and first half 2015 results presented in this press release were prepared on the adjusted basis described in Technip’s fourth quarter and full year 2014 results press release. These results reflect the financial reporting framework used for management purposes.

                         
€ million (except Diluted Earnings per Share)  2Q 14  2Q 15  Change  1H 14  1H 15  Change
Adjusted Revenue  2,615.4  3,098.4  18.5%  5,083.9  5,981.7  17.7%
Adjusted Underlying EBITDA1  303.0  353.0  16.5%  483.6  596.7  23.4%
Adjusted Underlying EBITDA Margin  11.6%  11.4%  (19)bp  9.5%  10.0%  46bp
Adjusted Underlying OIFRA2240.1281.517.2%359.9453.225.9%
Adjusted Underlying Operating Margin39.2%9.1%(9)bp7.1%7.6%50bp
One-off Charge (570.4) nm (570.4) nm
Other including Tax and Financial Effects (7.9) 80.5 nm (7.9) 58.6 nm
Underlying Net Income4  165.6  183.0  10.5%  232.8  291.0  25.0%
Adjusted OIFRA5240.197.1nm359.9268.8nm
Net Income of the Parent Company  157.7  (306.9)  nm  224.9  (220.8)  nm
Diluted Earnings per Share (€)   1.30   (2.71)   nm   1.88   (1.95)   nm
Order Intake   7,077   1,510       9,857   3,011    
Backlog   19,860   18,824       19,860   18,824    

1 Adjusted operating income from recurring activities after Income/(loss) of equity affiliates excluding exceptional items, depreciation and amortization.
2 (Adjusted) operating income from recurring activities after Income/(loss) of equity affiliates excluding exceptional items.
3 Adjusted operating income from recurring activities after Income/(loss) of equity affiliates excluding exceptional items, divided by adjusted revenue.
4 Net income of the parent company excluding exceptional items. See annex VI.
5 Adjusted operating income from recurring activities after Income/(loss) of equity affiliates.

Thierry Pilenko, Chairman and CEO, commented: “Second quarter results were in line with the expectations we set out in our July 6th announcement. During the quarter, we continued to pursue our key strategy initiatives, to position ourselves on significant new projects and we launched a major restructuring plan across the Group to address the challenging market outlook we anticipate.

“Subsea continued its outperformance: revenue grew 26%, and adjusted operating income from recurring activities of €250 million demonstrated a robust operating margin of 16.1%. During the quarter, good progress was made on projects across the world, as reflected in a strong vessel utilization rate of 89%. After announcing our alliance with FMC Technologies in March, we formally launched the Forsys Subsea joint venture together, on June 1st as planned.

“Onshore/Offshore grew revenues slightly faster than expected at 12%. Adjusted operating income from recurring activities is impacted by the one-off charge announced on July 6th. Stripping this out, underlying operating profits were €53 million, in line with expectations. We have progressed well on some of our key projects, such as Burgas in Bulgaria, Ethylene XXI in Mexico, RAPID in Malaysia and Prelude in Korea.

“Technip booked €1.5 billion of new orders, similar to the first quarter 2015 level, diversified and balanced between Subsea and Onshore/Offshore. This order intake reflects key elements of our strategy: a strong contribution from reimbursable and services contracts; success in areas such as Brazil pre-salt where we have technology leadership; positioning in early phase work for future projects such as the Browse FLNG in Australia and the Alexandria refinery in Egypt.

“In our July 6th announcement, we set out in detail our views on the market outlook and these have not changed: the oil and gas industry is likely to be adversely impacted for longer than anticipated by the downturn. Our restructuring plan targets savings in Technip’s cost base of €830 million, focusing the business on its core strengths.

“By acting early and decisively, Technip’s teams are mobilized to put the Group on the front foot in a challenging environment.

“Looking forward, we maintain our strategic direction and will continue to invest in, and expand, our capabilities. By having an earlier and broader view of projects, we are able to apply our technologies, the lessons learned from other projects and intelligent standardization to optimize project returns. Clients across the spectrum are responding positively to these initiatives, giving us confidence that our strategy will position Technip to deliver the lower project costs and value creation our industry needs.”

I. ORDER INTAKE AND BACKLOG

1. Second Quarter 2015 Order Intake

During second quarter 2015, Technip’s order intake was €1.5 billion. The breakdown by business segment was as follows:

         
Order Intake1(€ million)  2Q 2014  2Q 2015
Subsea   2,238   892
Onshore/Offshore 4,839 618
Total  7,077  1,510

Subsea order intake included new orders for an initial 50 kilometers of highly technological flexible pipes and associated equipment for the pre-salt in Brazil, to be produced in our manufacturing plants in Vitoria and Açu.

Also included are two EPCI deepwater projects in the US Gulf of Mexico, located in the Mississippi Canyon area: a project for new production pipeline systems on the Thunder Horse production unit, and a contract for the decommissioning of the Blind Faith brownfield development and installation of new subsea equipment supporting a floating production system.

1 Order intake includes all projects whose revenues are consolidated in our adjusted financial statements.

Onshore/Offshore order intake includes call-off on a range of reimbursable and services contracts. Technip was in addition awarded the front-end engineering design (FEED) for the Browse project for three FLNG units in the Browse Basin, offshore Australia. A second contract covering the engineering, procurement, construction and installation phases was also awarded to the Technip Samsung Consortium, subject to the client’s final investment decision.

In Vietnam, Technip, in consortium with Petrovietnam Technical Services Corporation, was awarded an engineering, procurement, construction and commissioning contract (EPCC) which covers the revamping of the ammonia plant at the existing Phu My Fertilizer Complex.

Technip was awarded a detailed engineering and procurement (EP) services contract for FPSO topsides to be located on the Libra field, offshore Brazil. This contract will be executed in Malaysia and the construction will take place at the Jurong Shipyard in Singapore.

Technip also won a Project Management Consultancy (PMC) contract in partnership with UNICO, a Japanese engineering consultant, for upgrading the Basra refinery in Iraq.

Listed in annex IV (b) are the main contracts announced since April 2015 and their approximate value if publicly disclosed.

2. Backlog by Geographic Area

At the end of second quarter 2015, Technip’s backlog was €18.8 billion, compared with €20.6 billion at the end of first quarter 2015 and €19.9 billion at the end of second quarter 2014.

The geographic split of the backlog is set out in the table below:

             
Backlog1 (€ million)  March 31, 2015  June 30, 2015  Change
Europe, Russia, Central Asia   8,662   7,764   (10.4)%
Africa 4,168 3,535 (15.2)%
Middle East 1,176 1,031 (12.3)%
Asia Pacific 2,596 2,511 (3.3)%
Americas 4,016 3,983 (0.8)%
Total  20,618  18,824  (8.7)%

3. Backlog Scheduling

An estimated 28% of the backlog is scheduled for execution in 2015.

             

Estimated Scheduling

as of June 30, 2015 (€ million)

 Subsea  Onshore/Offshore  Group
2015 (6 months)   2,619   2,656   5,275
2016 4,083 4,159 8,242
2017 and beyond 2,718 2,589 5,307
Total  9,420  9,404  18,824

II. SECOND QUARTER 2015 OPERATIONAL & FINANCIAL HIGHLIGHTS – ADJUSTED BASIS

On July 6th, the Group announced the launch of a restructuring plan addressing the downturn in the oil and gas market. Further details of the charge taken in the second quarter are given in note II.3 below, with additional comments where appropriate in the segment highlights.

1 Backlog includes all projects whose revenues are consolidated in our adjusted financial statements.

1.Subsea

Subsea main operations for the quarter were as follows:

  • In the Americas:
    • In the US Gulf of Mexico, welding activities were completed on Julia and Stones at our Mobile spoolbase and started to ramp-up on the Kodiak project. At the end of the quarter, Deep Blue was re-mobilized on the Julia project for its third installation trip, after completing its campaign in the North Sea.
    • In Brazil, flexible pipe production started for the pre-salt fields of Lula Alto and continued for the fields of Iracema Norte, Iracema Sul, Sapinhoá & Lula Nordeste and Sapinhoá Norte at our manufacturing plants in Vitoria and Açu.
  • In the North Sea, the Deep Blue completed its pipelay campaign on Quad 204 before returning to the US Gulf of Mexico. At the same time, the North Sea Atlantic started to work on Quad 204 for the pre-installation of new risers, after successful installation of the second cassette base frame on the Åsgard Subsea Compression project in Norway. Meanwhile, the Deep Energy completed its pipelay campaign on Kraken in Scotland, before mobilizing on the Prelude project at our Orkanger spoolbase and transiting to Asia Pacific. In Norway, the Apache II completed the umbilical and pipeline installation campaign on Snøhvit.
  • In West Africa, the Deep Pioneer was mobilized on the Block 15/06 development in Angola after a planned maintenance period in Namibia, while the Deep Orient continued its offshore campaign on the same project. Engineering and procurement phases progressed on other major projects, such as Moho Nord in Congo, T.E.N. in Ghana, and Kaombo in Angola.
  • In Asia Pacific, the G1201 completed the installation campaign of Block SK316 and was mobilized on the Malikai project in Malaysia. At the end of the quarter, the Deep Energy started the offshore campaign on the Prelude project in Australia. Engineering and procurement phases progressed on the Jangkrik and Bangka projects in Indonesia, for which flexible pipes are manufactured at our Asiaflex plant.

Overall, the Group vessel utilization rate for the second quarter of 2015 was 89%, compared with 88% for the second quarter of 2014, and substantially up on the 68% in the first quarter of 2015. In Brazil, the Sunrise 2000 vessel was demobilized in June, leaving the Technip fleet.

Subsea financial performance is set out in the following table:

             
€ million  2Q 2014  2Q 2015  Change
Subsea      
Adjusted Revenue 1,232.5 1,553.8 26.1%
Adjusted EBITDA 242.9 311.6 28.3%
Adjusted EBITDA Margin19.7%20.1%35bp
Adjusted OIFRA after Income/(Loss) of Equity Affiliates* 189.0 250.3 32.4%
Adjusted Operating Margin  15.3%  16.1%  77bp

* No one-off charge accounted in Adjusted Subsea OIFRA.

2. Onshore/Offshore

Onshore/Offshore performance in the second quarter reflects the market conditions described in our press release of July 6th which also sets out the corresponding restructuring plan. Of the one-off charge linked to this restructuring plan, €184 million was taken in adjusted Onshore/Offshore operating income from recurring activities. Accordingly, comments below reflect the adjusted underlying operating income from recurring activities, i.e., notably excluding this one-off charge.

Main operations for the quarter were as follows:

  • In the Middle East,construction continued on the Halobutyl elastomer facility in Saudi Arabia as well as the fabrication of the FMB platforms for Qatar. At the same time, the construction started on the Umm Lulu complex in Abu Dhabi.
  • In Asia Pacific, the central processing jacket and the bridge-linked wellhead platform sailed away to Block SK316, while the superlift of the topsides on the hull of Malikai tension leg platform (TLP) was successfully completed in Malaysia. In Korea, all remaining modules and the 135-meter flare were successfully lifted onto Petronas FLNG 1 hull, while all heavy modules are now on the Prelude FLNG hull. On RAPID project, the mobilization of the construction team started at site for piling. Meanwhile, the engineering and procurement phases continued on the Mangalore purified terephthalic acid (PTA) plant in India.
  • In Europe and Russia, the engineering and procurement phases progressed according to plan on the Yamal LNG project, while construction of the modules was pursued at all of the yards. Engineering ramped up on the ammonia plant in Slovakia, while in Bulgaria, the Burgas refinery’s new units were ready for start-up.
  • In the Americas, engineering and procurement activities moved forward for Sasol’s world-scale ethane cracker and derivative complex near Lake Charles, Louisiana, while construction continued on the Ethylene XXI petrochemical complex in Mexico and ramped up for the CPChem polyethylene plants in Texas. At the same time, the construction of the platform started on the Juniper project in Trinidad and Tobago.

Onshore/Offshore financial performance is set out in the following table:

             
€ million  2Q 2014  2Q 2015  Change
Onshore/Offshore      
Adjusted Revenue 1,382.9 1,544.6 11.7%
Adjusted Underlying OIFRA after Income/(Loss) of Equity Affiliates 72.8 53.2 (26.9)%
Adjusted Underlying Operating Margin5.3%3.4%(182)bp
Adjusted OIFRA after Income/(Loss) of Equity Affiliates 72.8 (131.2) nm
Adjusted Operating Margin  5.3%  (8.5)%   nm

Elsewhere, on Algiers refinery, Technip confirms that its involvement in this project has stopped at the request of its client, Sonatrach. As provided by the contract, both sides have initiated arbitration proceedings on certain claims. These proceedings are in the earliest stages. In Brazil, construction continued into its final stages on the RPBC project.

3. Group

On July 6th, Technip announced the launch of a restructuring plan with a total one-off charge of €650 million. Of this total, €570 million was booked in the second quarter: €184 million in operating income from recurring activities and €386 million in non-current operating result.

The Group’s adjusted operating income from recurring activities after income/(loss) of equity affiliates, including Corporate charges of €22 million, is set out in the following table:

             
€ million  2Q 2014  2Q 2015  Change
Group      
Adjusted Revenue 2,615.4 3,098.4 18.5%
Adjusted Underlying OIFRA after Income/(Loss) of Equity Affiliates 240.1 281.5 17.2%
Adjusted Underlying Operating Margin9.2%9.1%(9)bp
Adjusted OIFRA after Income/(Loss) of Equity Affiliates 240.1 97.1 (59.6)%
Adjusted Operating Margin  9.2%  3.1%  (605)bp

In the second quarter of 2015, compared to a year ago, the estimated translation impact from foreign exchange was positive €282 million on adjusted revenue and positive €17 million on adjusted operating income from recurring activities after income/(loss) of equity affiliates.

4. Adjusted Non-Current Items and Group Net Income

Adjusted non-current operating items of €(398) million were booked in the quarter, out of which €(386) million reflects part of the one-off charge referred to above.

Adjusted financial result in the second quarter of 2015 included €20 million of interest expense on long and short-term debt.

As the Group net income was a loss in the quarter, share subscription options, performance shares and convertible bonds had an anti-dilutive effect.

             
€ million (except Diluted Earnings per Share and Diluted Number of Shares)  2Q 2014  2Q 2015  Change
Adjusted OIFRA after Income/(Loss) of Equity Affiliates   240.1   97.1   (59.6)%
Adjusted Underlying OIFRA after Income/(Loss) of Equity Affiliates 240.1 281.5 17.2%
Adjusted Non-Current Operating Result (6.5) (397.8) nm
Adjusted Financial Result (17.5) (28.4) 62.3%
Adjusted Income Tax Expense (59.2) 24.2 nm
Adjusted Effective Tax Rate27.4%nmnm
Adjusted Non-Controlling Interests 0.8 (2.0) nm
Net Income of the Parent Company157.7(306.9)nm
Underlying Net Income165.6183.010.5%
Diluted Number of Shares 124,998,449 113,121,323 nm
Diluted Earnings per Share (€)  1.30  (2.71)  nm

5. Adjusted Cash Flow and Statement of Consolidated Financial Position

As of June 30, 2015, the adjusted net cash position was €1,415 million compared with €1,751 million as of March 31, 2015.

     
Adjusted Cash1 as of March 31, 2015  4,320.7
Adjusted Cash Generated from/(used in) Operating Activities   (141.3)
Adjusted Cash Generated from/(used in) Investing Activities (117.2)
Adjusted Cash Generated from/(used in) Financing Activities (125.0)
Adjusted FX Impacts   39.0
Adjusted Cash1 as of June 30, 2015  3,976.2

Adjustedcapital expenditures for the second quarter 2015 were €87 million, compared with €93 million one year ago.

The Group’s balance sheet remains robust and liquid. Adjustedshareholders’ equity of the parent company as of June 30, 2015, was €4,268 million, compared with €4,363 million as of December 31, 2014.

III. 2015 OBJECTIVES

  • Adjusted Subsea revenue between €5.2 and €5.5 billion, adjusted operating income from recurring activities2 at around €840 million
  • Adjusted Onshore/Offshore revenue around €6 billion, adjusted underlying operating income from recurring activities3 between €210 and €230 million

1 Adjusted cash and cash equivalents, including bank overdrafts.

2 Adjusted operating income from recurring activities after Income/(Loss) of Equity Affiliates.

3 Adjusted operating income from recurring activities after Income/(Loss) of Equity Affiliates excluding exceptional items.

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The information package on Second Quarter 2015 results includes this press release and the annexes which follow, as well as the presentation published on Technip’s website: www.technip.com

NOTICE

Today, Thursday, July 30, 2015, Chairman and CEO Thierry Pilenko, along with Group CFO Julian Waldron, will comment on Technip’s results and answer questions from the financial community during a conference call in English starting at 10:00 a.m. Paris time.

To participate in the conference call, you may call any of the following telephone numbers approximately 5 – 10 minutes prior to the scheduled start time:

France / Continental Europe:   +33 (0) 1 70 77 09 35
UK: +44 (0) 207 107 1613
USA: +1 855 402 7763

The conference call will also be available via a simultaneous, listen-only audio-cast on Technip’s website.

A replay of this conference call will be available approximately two hours following the conference call for three months on Technip’s website and at the following telephone numbers:

 

Telephone Numbers

 

Confirmation Code

France / Continental Europe: +33 (0) 1 72 00 15 00 294956#
UK: +44 (0) 203 367 9460 294956#
USA: +1 877 642 3018 294956#

Cautionary note regarding forward-looking statements

This press release contains both historical and forward-looking statements. These forward-looking statements are not based on historical facts, but rather reflect our current expectations concerning future results and events, and generally may be identified by the use of forward-looking words such as “believe”, “aim”, “expect”, “anticipate”, “intend”, “foresee”, “likely”, “should”, “planned”, “may”, “estimates”, “potential” or other similar words. Similarly, statements that describe our objectives, plans or goals are or may be forward-looking statements. These forward-looking statements involve known and unknown risks, uncertainties and other factors that may cause our actual results, performance or achievements to differ materially from the anticipated results, performance or achievements expressed or implied by these forward-looking statements. Risks that could cause actual results to differ materially from the results anticipated in the forward-looking statements include, among other things: our ability to successfully continue to originate and execute large services contracts, and construction and project risks generally; the level of production-related capital expenditure in the oil and gas industry as well as other industries; currency fluctuations; interest rate fluctuations; raw material (especially steel) as well as maritime freight price fluctuations; the timing of development of energy resources; armed conflict or political instability in the Arabian-Persian Gulf, Africa or other regions; the strength of competition; control of costs and expenses; the reduced availability of government-sponsored export financing; losses in one or more of our large contracts; U.S. legislation relating to investments in Iran or elsewhere where we seek to do business; changes in tax legislation, rules, regulation or enforcement; intensified price pressure by our competitors; severe weather conditions; our ability to successfully keep pace with technology changes; our ability to attract and retain qualified personnel; the evolution, interpretation and uniform application and enforcement of International Financial Reporting Standards (IFRS), according to which we prepare our financial statements as of January 1, 2005; political and social stability in developing countries; competition; supply chain bottlenecks; the ability of our subcontractors to attract skilled labor; the fact that our operations may cause the discharge of hazardous substances, leading to significant environmental remediation costs; our ability to manage and mitigate logistical challenges due to underdeveloped infrastructure in some countries where we are performing projects.

Some of these risk factors are set forth and discussed in more detail in our Annual Report. Should one of these known or unknown risks materialize, or should our underlying assumptions prove incorrect, our future results could be adversely affected, causing these results to differ materially from those expressed in our forward-looking statements. These factors are not necessarily all of the important factors that could cause our actual results to differ materially from those expressed in any of our forward-looking statements. Other unknown or unpredictable factors also could have material adverse effects on our future results. The forward-looking statements included in this release are made only as of the date of this release. We cannot assure you that projected results or events will be achieved. We do not intend, and do not assume any obligation to update any industry information or forward-looking information set forth in this release to reflect subsequent events or circumstances.

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This press release does not constitute an offer or invitation to purchase any securities of Technip in the United States or any other jurisdiction. Securities may not be offered or sold in the United States absent registration or an exemption from registration. The information contained in this presentation may not be relied upon in deciding whether or not to acquire Technip securities.

This presentation is being furnished to you solely for your information, and it may not be reproduced, redistributed or published, directly or indirectly, in whole or in part, to any other person. Non-compliance with these restrictions may result in the violation of legal restrictions of the United States or of other jurisdictions.

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Technip is a world leader in project management, engineering and construction for the energy industry.

From the deepest Subsea oil & gas developments to the largest and most complex Offshore and Onshore infrastructures, our 37,500 people are constantly offering the best solutions and most innovative technologies to meet the world’s energy challenges.

Present in 48 countries, Technip has state-of-the-art industrial assets on all continents and operates a fleet of specialized vessels for pipeline installation and subsea construction.

Technip shares are listed on the Euronext Paris exchange, and its ADR is traded in the US on the OTCQX marketplace as an American Depositary Receipt (OTCQX: TKPPY).

ANNEX I (a) 1
ADJUSTED CONSOLIDATED STATEMENT OF INCOME

 

       
Second Quarter

Not audited

 First Half

Not audited

€ million (except Diluted Earnings per Share and Diluted Number of Shares)  2014  2015  Change  2014  2015  Change
Revenue  2,615.4  3,098.4  18.5%  5,083.9  5,981.7  17.7%
Gross Margin   416.0   266.6   (35.9)%   713.4   602.6   (15.5)%
Research & Development Expenses (18.4)   (23.7)   28.8% (36.0)   (41.6)   15.6%
SG&A and Other (163.7) (157.5) (3.8)% (326.2) (308.9) (5.3)%
Share of Income/(Loss) of Equity Affiliates   6.2   11.7   88.7%   8.7   16.7   92.0%
OIFRA after Income/(Loss) of Equity Affiliates  240.1  97.1  nm  359.9  268.8  nm
Non-Current Operating Result (6.5) (397.8) nm (6.5) (403.8) nm
Operating Income  233.6  (300.7)  nm  353.4  (135.0)  nm
Financial Result (17.5) (28.4) 62.3% (41.7) (67.3) 61.4%
Income/(Loss) before Tax  216.1  (329.1)  nm  311.7  (202.3)  nm
Income Tax Expense (59.2) 24.2 nm (85.5) (13.9) nm
Non-Controlling Interests 0.8 (2.0) nm (1.3) (4.6) nm
Net Income/(Loss) of the Parent Company  157.7  (306.9)  nm  224.9  (220.8)  nm
                         
Diluted Number of Shares2   124,998,449   113,121,323   nm   124,901,758   113,353,706   nm
Diluted Earnings per Share (€)  1.30  (2.71)  nm  1.88  (1.95)  nm

1 Note that statements disclosed in annex I(a) and I(c) do not report underlying OIFRA. Please, refer to annex VI, page 21, for the underlying net income reconciliation.
2 As per IFRS, diluted earnings per share are calculated by dividing profit or loss attributable to the Parent Company’s Shareholders, restated for financial interest related to dilutive potential ordinary shares, by the weighted average number of outstanding shares during the period, plus the effect of dilutive potential ordinary shares related to the convertible bonds, dilutive stock options and performance shares calculated according to the “Share Purchase Method” (IFRS 2), less treasury shares. In conformity with this method, anti-dilutive stock options are ignored in calculating EPS. Dilutive options are taken into account if the subscription price of the stock options plus the future IFRS 2 charge (i.e. the sum of annual charge to be recorded until the end of the stock option plan) is lower than the average market share price during the period. As the Group net income is a loss in the quarter, share subscription options, performance shares and convertible bonds have an anti-dilutive effect.

ANNEX I (b)
FOREIGN CURRENCY CONVERSION RATES

 

       
Closing Rate as of  Average Rate of
   Dec. 31, 2014  Jun. 30, 2015  2Q 2014  2Q 2015  1H 2014  1H 2015
USD for 1 EUR   1.21   1.12  

1.37

  1.11   1.37   1.12
GBP for 1 EUR   0.78   0.71   0.81   0.72   0.82   0.73
BRL for 1 EUR   3.22   3.47   3.06   3.39   3.15   3.31
NOK for 1 EUR   9.04   8.79   8.21   8.56   8.28   8.64

ANNEX I (c) 1
ADJUSTED ADDITIONAL INFORMATION BY BUSINESS SEGMENT

 

       
Second Quarter

Not audited

 First Half

Not audited

€ million  2014  2015  Change  2014  2015  Change

SUBSEA

       
Revenue 1,232.5 1,553.8 26.1% 2,241.8 2,841.4 26.7%
Gross Margin 257.9 314.0 21.8% 382.7 540.3 41.2%
OIFRA after Income/(Loss) of Equity Affiliates 189.0 250.3 32.4% 244.2 415.5 70.1%
Operating Margin15.3%16.1%77bp10.9%14.6%373bp
Depreciation and Amortization (53.9) (61.3) 13.7% (106.0) (123.7) 16.7%
EBITDA 242.9 311.6 28.3% 350.2 539.2 54.0%
EBITDA Margin  19.7%  20.1%  35bp  15.6%  19.0%  336bp

ONSHORE/OFFSHORE

Revenue 1,382.9 1,544.6 11.7% 2,842.1 3,140.3 10.5%
Gross Margin 158.1 (47.4) nm 330.7 62.3 nm
OIFRA after Income/(Loss) of Equity Affiliates 72.8 (131.2) nm 158.7 (107.7) nm
Operating Margin5.3%(8.5)%nm5.6%(3.4)%nm
Depreciation and Amortization   (9.0)   (10.2)   13.3%   (17.7)   (19.8)   11.9%

CORPORATE

OIFRA after Income/(Loss) of Equity Affiliates (21.7) (22.0) 1.4% (43.0) (39.0) (9.3)%
Depreciation and Amortization            

1 Note that statements disclosed in annex I(a) and I(c) do not report underlying OIFRA. Please, refer to annex VI, page 21, for the underlying net income reconciliation.

ANNEX I (d)
ADJUSTED REVENUE BY GEOGRAPHICAL AREA

 

       
Second Quarter

Not audited

 First Half

Not audited

€ million  2014  2015  Change  2014  2015  Change
Europe, Russia, Central Asia   1,020.4   1,154.5   13.1%   1,709.6   2,182.7   27.7%
Africa   237.7   524.7   120.7%   479.7   943.7   96.7%
Middle East   248.7   220.5   (11.3)%   654.9   505.2   (22.9)%
Asia Pacific   490.8   482.8   (1.6)%   912.0   958.9   5.1%
Americas   617.8   715.9   15.9%   1,327.7   1,391.2   4.8%
TOTAL  2,615.4  3,098.4  18.5%  5,083.9  5,981.7  17.7%

ANNEX II
ADJUSTED CONSOLIDATED STATEMENT OF FINANCIAL POSITION

 

       
Dec. 31, 2014

Audited

 Jun. 30, 2015

Not audited

€ million    
Fixed Assets 6,414.2 6,617.2
Deferred Tax Assets   391.0   496.1
Non-Current Assets  6,805.2  7,113.3
Construction Contracts – Amounts in Assets 756.3 952.5
Inventories, Trade Receivables and Other 3,297.0 3,826.3
Cash & Cash Equivalents   3,738.3   3,976.5
Current Assets  7,791.6  8,755.3
Assets Classified as Held for Sale  3.2  28.4
Total Assets  14,600.0  15,897.0
         
Shareholders’ Equity (Parent Company) 4,363.4 4,268.2
Non-Controlling Interests   11.8   20.3
Shareholders’ Equity  4,375.2  4,288.5
Non-Current Financial Debts 2,356.6 1,671.7
Non-Current Provisions 232.9 247.2
Deferred Tax Liabilities and Other Non-Current Liabilities   249.1   266.7
Non-Current Liabilities  2,838.6  2,185.6
Current Financial Debts 256.4 890.3
Current Provisions 328.3 551.0
Construction Contracts – Amounts in Liabilities 2,258.2 2,491.1
Trade Payables & Other   4,543.3   5,490.5
Current Liabilities  7,386.2  9,422.9
Total Shareholders’ Equity & Liabilities  14,600.0  15,897.0
         
Net Cash Position  1,125.3  1,414.5
 
Adjusted Statement of Changes in Shareholders’ Equity (Parent Company)
Not audited (€ million):
Shareholders’ Equity as of December 31, 2014  4,363.4
Net Income (220.8)
Other Comprehensive Income 172.6
Capital Increase 158.2
Treasury Shares 4.6
Dividends Paid (225.8)
Other 16.0
Shareholders’ Equity as of June 30, 2015  4,268.2

ANNEX III (a)
ADJUSTED CONSOLIDATED STATEMENT OF CASH FLOWS

 

   
First Half

Not audited

€ million  2014  2015
Net Income/(Loss) of the Parent Company 224.9     (220.8)  
Depreciation & Amortization of Fixed Assets 123.7 186.1
Stock Options and Performance Share Charges 20.5 15.2
Non-Current Provisions (including Employee Benefits) 7.7 137.6
Deferred Income Tax 8.4 (100.6)
Net (Gains)/Losses on Disposal of Assets and Investments 7.9 (26.7)
Non-Controlling Interests and Other 10.6 7.7
 
Cash Generated from/(used in) Operations403.7(1.5)
 
Change in Working Capital Requirements(194.9)370.9
 
Net Cash Generated from/(used in) Operating Activities208.8369.4
                 
Capital Expenditures (185.8) (144.6)
Proceeds from Non-Current Asset Disposals 17.0 2.0
Acquisitions of Financial Assets (2.5)
Acquisition Costs of Consolidated Companies, Net of Cash acquired (5.9) (32.4)
 
Net Cash Generated from/(used in) Investing Activities(174.7)(177.5)
                 
Net Increase/(Decrease) in Borrowings (13.5) (107.5)
Capital Increase 8.1 21.3
Dividends Paid (206.5) (88.9)
Share Buy-Back and Other (41.8)
 
Net Cash Generated from/(used in) Financing Activities(253.7)(175.1)
                 
Net Effects of Foreign Exchange Rate Changes37.2222.0
 
Net Increase/(Decrease) in Cash and Cash Equivalents(182.4)238.8
                 
Bank Overdrafts at Period Beginning (2.4) (0.9)
Cash and Cash Equivalents at Period Beginning 3,205.4 3,738.3
Bank Overdrafts at Period End (2.8) (0.3)
Cash and Cash Equivalents at Period End 3,023.4 3,976.5
(182.4)238.8
                 

ANNEX III (b)
ADJUSTED CASH & FINANCIAL DEBTS

 

       
€ million  Dec. 31, 2014

Audited

 Jun. 30, 2015

Not audited

Cash Equivalents 1,809.4   2,052.9
Cash 1,928.9 1,923.6
Cash & Cash Equivalents (A)  3,738.3  3,976.5
Current Financial Debts 256.4 890.3
Non-Current Financial Debts 2,356.6 1,671.7
Gross Debt (B)  2,613.0  2,562.0
Net Cash Position (A – B)  1,125.3  1,414.5

ANNEX IV (a)
BACKLOG BY BUSINESS SEGMENT

 

           
€ million  As of

Dec. 31, 2014

Audited

 As of

Jun. 30, 2015

Not audited

 Change
Subsea 9,727.8   9,420.0   (3.2)%
Onshore/Offshore 11,208.4 9,404.0 (16.1)%
Total  20,936.2  18,824.0  (10.1)%

ANNEX IV (b)
CONTRACT AWARDS
Not audited

The main contracts we announced during second quarter 2015 were the following:

Subsea Segment:

  • Brownfield contract for the Triton floating production storage and offloading (FPSO) vessel, covering project management and engineering, with the installation of two flexible risers and one dynamic umbilical: Dana Petroleum, 193 kilometers east of Aberdeen in the central North Sea, at a water depth of approximately 90 meters, Scotland,
  • Contract for the design, engineering, fabrication, installation and pre-commissioning of the new production pipeline systems on the south side of the Thunder Horse production drilling quarters unit, at a water depth of approximately 1,900 meters: BP Exploration & Production Inc., Mississippi Canyon Blocks 778 and 822, US Gulf of Mexico,
  • Contract for the decommissioning of the brownfield development and installation of new subsea equipment supporting a floating production system, in a water depth of approximately 2,000 meters: Chevron North America Exploration and Production Company, Mississippi Canyon, US Gulf of Mexico.

Onshore/Offshore Segment:

  • Front end engineering design (FEED) contract for two tension leg platforms (TLPs) for the Liuhua 11-1 and 16-2 joint development project, covering the design and engineering of the topsides (including two drilling rigs), hulls, mooring and riser systems: China National Offshore Oil Corporation (CNOOC),in the South China Sea, People’s Republic of China,
  • Front end engineering design (FEED) and detailed engineering design contract for the development of a new gas pipeline of more than 1,700 kilometers, which will transport gas from the Camisea field to Southern Peru: Consorcio Constructor Ductos del Sur, Peru,
  • Project Management Consultancy (PMC) contract covering the engineering, procurement, construction, commissioning, start-up and warranty management phase of the Basra refinery upgrading: South Refineries Company (SRC) – Ministry of Oil, Iraq,
  • Significant engineering, procurement, construction and commissioning contract that covers the revamping of the ammonia plant at the existing Phu My Fertilizer Complex: PetroVietnam Fertilizer and Chemicals Corporation (PVFCCo), southern Ba Ria-Vung Tau Province, Vietnam,
  • Topsides detailed engineering and procurement services contract part of the conversion of a shuttle tanker into a floating, production, storage and offloading (FPSO) vessel: Jurong Shipyard Pte Ltd, Jurong Shipyard, Singapore.

Since June 30, 2015, Technip has also announced the award of the following contracts, which were included in the backlog as of June 30, 2015:

Subsea Segment:

  • Engineering, procurement, construction, installation and commissioning contract for the tie-in of PETRONAS first Floating Liquefied Natural Gas (PFLNG1) facility to KAKG-A platform, covering the procurement and installation of a 3.2 kilometers flexible flowline between the existing KAKG-A central processing platform in Kanowit field to the PFLNG1 riser: PETRONAS Carigali, Kanowit field, 200 kilometers offshore Bintulu, East Malaysia.

Onshore/Offshore Segment:

  • Browse floating liquefied natural gas (FLNG) project, which covers the realization and installation of three FLNG units. The contract awarded covers the front-end engineering design (FEED) elements of the Browse FLNG project. A second contract covering the engineering, procurement, construction and installation, awarded to Technip Samsung Consortium is subject to the final investment decision from the client: Shell Gas & Power Developments BV & Woodside Energy Limited,Brecknock, Calliance and Torosa fields in the Browse Basin, 425 kilometers North of Broome, Western Australia,
  • Project Management Consultancy (PMC) contract for a project designed to transport gas from the Shah Deniz field to the European market. The services will include the overall project and site management, procurement and subcontracting for all the EPC packages throughout the engineering, procurement and construction phases, as well as warranty management and the project close-out: Trans Adriatic Pipeline (TAP) AG, Italy, Albania and Greece.

Since June 30, 2015, Technip has also announced the award of the following contracts, which were not included in the backlog as of June 30, 2015:

Onshore/Offshore Segment:

  • Contract for a project to modernize and expand the MIDOR refinery, aiming at improving the production quality of the plant, considered the most advanced of the African continent: Midor (Middle East Oil Refinery), near Alexandria, Egypt,
  • Contract for the modernization project of the Assiut refinery, designed to refine the “bottom of the barrel” and aiming at maximizing diesel production: Egyptian General Petroleum Corporation (EGPC) and Assiut Oil Refining Company (ASORC), Upper Egypt.

****

The annex V presents the first half IFRS consolidated financial statements and a reconciliation to the adjusted basis.

****

ANNEX V (a)
CONSOLIDATED STATEMENT OF INCOME
Not audited

   
€ millionFirst Half
(except Diluted Earnings per Share, and Diluted Number of Shares)  2014 IFRS  2015 IFRS  Change  Adjustments  2015 Adjusted
Revenue  4,841.9  5,336.4  10.2%645.3  5,981.7
Gross Margin   713.5   597.5   (16.3)%5.1  602.6
Research & Development Expenses (36.0)   (41.6)   15.6%  (41.6)
SG&A and Other (326.1) (308.7) (5.3)%(0.2)(308.9)
Share of Income/(Loss) of Equity Affiliates   (8.9)   17.5   nm(0.8)  16.7
OIFRA after Income/(Loss) of Equity Affiliates  342.5  264.7  nm4.1  268.8
Non-Current Operating Result (6.5) (403.8) nm(403.8)
Operating Income  336.0  (139.1)  nm4.1  (135.0)
Financial Result (42.5) (66.2) 55.8%(1.1)(67.3)
Income/(Loss) before Tax  293.5  (205.3)  nm3.0  (202.3)
Income Tax Expense (67.3) (10.9) nm(3.0)(13.9)
Non-Controlling Interests (1.3) (4.6) nm(4.6)
Net Income/(Loss) of the Parent Company  224.9  (220.8)  nm    (220.8)
               
Diluted Number of Shares   124,901,758   113,353,706   nm
Diluted Earnings per Share (€)  1.88  (1.95)  nm

ANNEX V (b)
CONSOLIDATED STATEMENT OF FINANCIAL POSITION

               
€ million  

Dec. 31, 2014
IFRS
(audited)

 

June 30, 2015
IFRS
(not audited)

Adjustments  

June 30, 2015
Adjusted
(not audited)

Fixed Assets 6,452.5   6,662.0(44.8)  6,617.2
Deferred Tax Assets   366.0   473.123.0  496.1
Non-Current Assets  6,818.5  7,135.1(21.8)  7,113.3
Construction Contracts – Amounts in Assets 755.1 952.5952.5
Inventories, Trade Receivables and Other 3,157.4 3,566.3260.03,826.3
Cash & Cash Equivalents   2,685.6   2,499.71,476.8  3,976.5
Current Assets  6,598.1  7,018.51,736.8  8,755.3
Assets Classified as Held for Sale  3.2  28.4  28.4
Total Assets  13,419.8  14,182.01,715.0  15,897.0
               
Shareholders’ Equity (Parent Company) 4,363.4 4,268.24,268.2
Non-Controlling Interests   11.8   20.3  20.3
Shareholders’ Equity  4,375.2  4,288.5  4,288.5
Non-Current Financial Debts 2,356.6 1,671.71,671.7
Non-Current Provisions 231.6 246.01.2247.2
Deferred Tax Liabilities and Other Non-Current Liabilities   236.8   255.711.0  266.7
Non-Current Liabilities  2,825.0  2,173.412.2  2,185.6
Current Financial Debts 256.4 890.3890.3
Current Provisions 326.3 549.02.0551.0
Construction Contracts – Amounts in Liabilities 1,256.1 1,079.81,411.32,491.1
Trade Payables & Other   4,380.8   5,201.0289.5  5,490.5
Current Liabilities  6,219.6  7,720.11,702.8  9,422.9
Total Shareholders’ Equity & Liabilities  13,419.8  14,182.01,715.0  15,897.0
 
Statement of Changes in Shareholders’ Equity (Parent Company)
IFRS, Not audited (€ million):
Shareholders’ Equity as of December 31, 2014  4,363.4
Net Income (220.8)
Other Comprehensive Income 172.6
Capital Increase 158.2
Treasury Shares 4.6
Dividends Paid (225.8)
Other 16.0
Shareholders’ Equity as of June 30, 2015  4,268.2

ANNEX V (c)
CONSOLIDATED STATEMENT OF CASH FLOW
Not audited

   
First Half
€ million  2014 IFRS  2015 IFRS  Adjustments  2015 Adjusted
Net Income/(Loss) of the Parent Company 224.9     (220.8)      (220.8)  
Depreciation & Amortization of Fixed Assets 123.7 186.1186.1
Stock Options and Performance Share Charges 20.4 15.215.2
Non-Current Provisions (including Employee Benefits) 7.7 137.6137.6
Deferred Income Tax (8.5) (96.8)(3.8)(100.6)
Net (Gains)/Losses on Disposal of Assets and Investments 7.9 (26.7)(26.7)
Non-Controlling Interests and Other 28.2 6.90.87.7
 
Cash Generated from/(used in) Operations404.31.5(3.0)(1.5)
 
Change in Working Capital Requirements(776.7)56.2314.7370.9
 
Net Cash Generated from/(used in) Operating Activities(372.4)57.7311.7369.4
                               
Capital Expenditures (185.8) (144.4)(0.2)(144.6)
Proceeds from Non-Current Asset Disposals 17.0 2.02.0
Acquisitions of Financial Assets (2.5)(2.5)
Acquisition Costs of Consolidated Companies, Net of Cash acquired (5.9) (32.4)(32.4)
 
Net Cash Generated from/(used in) Investing Activities(174.7)(177.3)(0.2)(177.5)
                               
Net Increase/(Decrease) in Borrowings (13.5) (107.6)0.1(107.5)
Capital Increase 8.1 21.321.3
Dividends Paid (206.5) (88.9)(88.9)
Share Buy-Back and Other (41.8)
 
Net Cash Generated from/(used in) Financing Activities(253.7)(175.2)0.1(175.1)
                               
Net Effects of Foreign Exchange Rate Changes29.4109.5112.5222.0
 
Net Increase/(Decrease) in Cash and Cash Equivalents(771.4)(185.3)424.1238.8
                               
Bank Overdrafts at Period Beginning (2.4) (0.9)(0.9)
Cash and Cash Equivalents at Period Beginning 2,989.1 2,685.61,052.73,738.3
Bank Overdrafts at Period End (2.8) (0.3)(0.3)
Cash and Cash Equivalents at Period End 2,218.1 2,499.71,476.83,976.5
(771.4)(185.3)424.1238.8
                               

ANNEX VI
UNDERLYING NET INCOME RECONCILIATION
Not audited

   
€ millionSecond Quarter

2015

   
Net Income of the Parent Company(306.9)
One-off charge in OIFRA 184.4
Charges from Non-Current Activities 386.0
Other 11.8
Taxes & Financial Result (92.3)
Underlying Net Income183.0

Technip
Analyst and Investor Relations
Kimberly Stewart, +33 (0) 1 47 78 66 74
kstewart@technip.com
or
Aurélia Baudey-Vignaud, +33 (0) 1 85 67 43 81
abaudeyvignaud@technip.com
or
Michèle Schanté, +33 (0) 1 47 78 67 32
mschante@technip.com
or
Public Relations
Laure Montcel, +33 (0)1 49 01 87 81
lmontcel@technip.com
Technip’s website http://www.technip.com
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