SECURITIES
AND EXCHANGE COMMISSION
Washington, D.C. 20549
Form 6-K
REPORT OF FOREIGN
ISSUER
Pursuant to Rule 13a-16 or 15d-16 of
the Securities Exchange Act of 1934
For the month of May 2015
Eni S.p.A.
(Exact name of Registrant as specified in its
charter)
Piazzale Enrico
Mattei 1 - 00144 Rome, Italy
(Address of principal executive offices)
(Indicate by check mark whether the registrant files or will file annual reports under cover of Form 20-F or Form 40-F.)
Form 20-F x Form 40-F o
(Indicate by check mark whether the registrant by furnishing the information contained in this Form is also thereby furnishing the information to the Commission pursuant to Rule 12g3-2b under the Securities Exchange Act of 1934.)
Yes o No x
(If Yes is marked, indicate below the file number assigned to the registrant in connection with Rule 12g3-2(b): )
Summary annual review (Eni in 2014)
Press Release dated May 13, 2015
Ordinary Shareholders Meeting Resolutions
Press Release dated May 31, 2015
SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, hereunto duly authorised.
Eni S.p.A. |
||||
Name: Antonio Cristodoro | ||||
Title: | Head of Corporate Secretary's Staff Office | |||
Date: May 31, 2015
Fact Book 2014 | ||||||||||
Contents | Enis
Fact Book is a supplement to Enis Integrated Annual
Report and is designed to provide supplemental financial
and operating information. It contains certain forward-looking statements in particular under the section "Outlook" regarding capital expenditure, dividends, buyback program, allocation of future cash flow from operations evolution of financial structure, future operating performance, targets of production and sale growth, execution of projects. By their nature, forward-looking statements involve risks and uncertainties because they relate to events and depend on circumstances that will or may occur in the future. Actual results may differ from those expressed in such statements, depending on a variety of factors, including the timing of bringing new fields on stream; managements ability in carrying out industrial plans and in succeeding in commercial transactions; future levels of industry product supply; demand and pricing; operational problems; general economic conditions; geopolitical factors including international tensions, social and political instability, changes in the economic and legal frameworks in Enis countries of operations, regulation of the oil&gas industry, power generation and environmental field, development and use of new technologies; changes in public expectations and other changes in business conditions; the actions of competitors. |
|||||||||
Eni at a glance | 4 | |||||||||
Enis business model | 10 | |||||||||
Exploration & Production | 12 | |||||||||
Gas & Power | 38 | |||||||||
Refining & Marketing | 46 | |||||||||
Versalis | 56 | |||||||||
Engineering & Construction | 60 | |||||||||
Tables | ||||||||||
Financial Data | 66 | |||||||||
Employees | 81 | |||||||||
Supplemental oil and gas information | 82 | |||||||||
Quarterly information | 101 | |||||||||
Eni Fact Book Eni at a glance
Eni at a glance |
Results In 2014, in spite of an unfavorable trading environment, Eni delivered excellent results underpinned by record cash flow generation. The performance was driven by the increased contribution from upstream production and the accelerated restructuring of the mid and downstream businesses. Adjusted operating profit of euro 11.57 billion and adjusted net profit of euro 3.71 billion declined by 9% and 16%, respectively, compared to 2013. The mid and downstream businesses reported a euro 1.2 billion improvement driven by contract renegotiations, capacity restructuring and downsizing and cost efficiencies. These positives helped offset the decline of the E&P segment due to lower Brent prices. Additionally, 2014 results were reduced by the loss on the mark-to-market interests in Galp and Snam which underlay two convertible bonds (loss of euro 0.22 billion). Net profit of euro 1.29 billion was impacted by extraordinary charges, net of tax effect, of euro 1.41 billion, which related to asset impairments and the write off of certain deferred tax assets of Italian subsidiaries, as well as the alignment of crude oil and product inventories to current market prices for euro 1 billion. The 75% reduction from 2013 is attributable to the recognition in the past year of sizeable gains on the divestment of a 20% stake in the Mozambique discovery and on the revaluation of Enis interest in Artic Russia for an overall euro 4.7 billion. |
Cash flow of
euro 15.1 billion was the best result of the last six
years, supported by a reduced working capital in E&P,
G&P and Saipem. Proceeds from disposals were euro
3.68 billion and mainly related to the divestment of
Enis share in Artic Russia, an 8% interest in Galp
and in the South Stream project. These cash inflows
funded capital expenditure of euro 12.24 billion, focused
on upstream activities, dividend payments (euro 4
billion) and share repurchases (euro 0.38 billion), also
reducing the Groups net debt by euro 1.28 billion. As of December 31, 2014, leverage reduced to 0.22, from 0.25 at December 31, 2013. Dividend > The Companys robust results and strong fundamentals underpin a dividend distribution of euro 1.12 per share (euro 1.10 in 2013) of which euro 0.56 per share paid as interim dividend in September 2014. Share repurchases in 2014 were 21.66 million for a cash outlay of euro 0.38 billion, together with the dividend this ensured a distribution yield of 8.3%. Hydrocarbon production > In 2014, Enis hydrocarbon production was 1.598 million boe/d, up by 0.6% from 2013 on a homogeneous basis i.e. excluding the impact of the divestment of Enis interest in Artic Russia. Production increases in the United Kingdom, Algeria, the United States and Angola, more than offset mature fields decline. Start-ups and ramp-ups of new fields contributed 126 kboe/d. Proved oil and natural gas reserves > Proved oil and gas reserves as of December 31, 2014 were 6.6 bboe. The reserve replacement ratio was 112%. The reserve life index is 11.3 years. |
- 4 -
Eni Fact Book Eni at a glance
Development of new fields > In 2014, the West
Hub project, located offshore in Block 15/06 in Angola,
and Nené project in Block Marine XII in Congo were
started up, setting the industry benchmark in terms of
time-to-market. Exploration successes > In 2014, Eni continued its track record of exploratory success. Additions to the Companys resource base were approximately 900 million boe, at a competitive cost of $2.1 per barrel. Main discoveries in Angola, Congo, Ecuador, Indonesia and Gabon were made near-field and characterized by a short time-to-market. Renegotiation of long-term gas supply contracts and take-or-pay reduction > Following the renegotiation of a number of the main long-term supply contracts, gas prices and related trends were better aligned to market conditions. 70% of long-term gas supply portfolio is now indexed to hub prices. Furthermore, the cash advances paid to suppliers due to the take-or-pay clause in those long-term supply contracts were reduced by euro 0.66 billion thanks to contract renegotiation and sales optimization. Turnaround in refining
and Chemicals >
In 2014, the turnaround plan in the R&M
achieved a cut of up to 30% of Enis refining
capacity compared to 2012 with the agreement on the
conversion of the Gela refinery, the start-up of the
green plant in Venice and the disposal of Enis
interest in a refinery in East Europe. Overall the
capacity utilization rate increased from the previous
year, driving down the breakeven margin of Enis
refineries below 6 $/bbl. Restructuring of
petrochemical activities in Sardinia > Operations at the
green chemical project of Matrìca started up in 2014,
marking the full conversion of the Porto Torres site. |
Sustainability performance Safety > In 2014, Eni continued to implement the communication and training program "Eni in safety", with workshops dedicated to Enis employees. The benefit of these and other programs and investments in safety supported a positive trend in the injury frequency rate relating to employees and contractors which improved for the tenth consecutive year (down by 12.6% from 2013). Notwithstanding the 27% decrease in the fatality index, four fatal accidents occurred in 2014. Transparency in Corporate Reporting > In 2014, Eni ranked first in a worldwide survey made by Transparency International about transparency in corporate reporting. The survey analyzed three areas: anti-bribery programs, the organization (e.g. information on subsidiaries, joint arrangements and associates) and the publication of key economic and financial data related to the activities in each country where the company operates. LEAD Board Program > Eni is one of the six companies in the world to adhere to the pilot phase of the UN Global Compact LEAD Board Program, committed to the Board of Directors of certain companies, in order to strengthen their awareness on sustainability issues. During the first module on "The materiality of sustainability" Enis Board of Directors discussed on material sustainability issues leading the company to create sustainable value. The initiative will continue in 2015. |
- 5 -
Eni Fact Book Strategy
Strategy
Industrial Plan In order to cope with a radically changed price environment, the Company outlined for the next four-year period an action plan which comprises a number of rigorous initiatives and objectives in order to mitigate the impact of lower oil prices and to preserve a robust financial structure, particularly in the short-to-medium term. Against the backdrop of a low price environment, our primary target remains cash generation which will be underpinned by well-designed industrial actions, capital discipline, focus on upstream activities and a large disposal plan. In approving the capital expenditure plan the Company selected high-return projects with short pay-back periods; this optimization will result in a euro 47.8 billion capital expenditure in the next four years, down by approximately 17% compared to previous plan, at the same exchange rate. The disposal plan, amounting to more than euro 8 billion in the 2015-2018 period, is based on the anticipated monetization of exploratory discoveries, optimization of the upstream portfolio which will be refocused based on strategic consideration and on the evaluation of the geopolitical risk rationalization of midstream and downstream portfolio, and the divestment of residual interests in Snam and Galp. In the years 2015-2016 cash flow from operations will be able to fund projected capital expenditure on our Brent price scenario of 63 $/bbl on average. |
In the subsequent years,
under our planning assumption of a recovery in crude oil
prices at 85 $/bbl on average in the years 2017-2018 up
to the long-term Brent price of 90 $/bbl, and considering
our industrial actions, we will able to increase our cash
flow from operations by 40% thus generating a significant
surplus over the projected level of capital expenditure. In brief, the Company forecasts that the planned industrial actions, the selective approach to capital expenditure and the disposal plan will enable Eni to preserve a robust financial structure, targeting a leverage below the ceiling of 0.30 throughout the oil cycle. Dividend
policy For further information on main strategic guidelines and 2015-2018 key targets, see chapter "Enis business model" and section "Strategy" of each segment of activity. |
Strategic pillars | 2014 Achievements | 2015-2018 Plan | ||
Disciplined CAPEX plan | - euro 12.6 bln capital
expenditure - down by 3.6% from 2013 |
- 17% reduction vs. prior plan - 45% unsanctioned capex |
||
Cost efficiency | -
euro 250 mln G&A cost reduction - OPEX per boe at $8.4 |
-
G&A reduced by 25% with savings of approximately euro
2 bln - Unitary OPEX reduced by 7% |
||
Assets disposals | - euro 3.7 bln disposal of assets | - euro 8 bln disposal plan | ||
Robust balance sheet | - Leverage at 0.22 from 0.25 reported in 2013 | - 0.30 leverage threshold | ||
Dividend policy | - Distribution Yield at 8.3% - Dividend per share of euro 1.12 - Payout > 300% |
- Competitive and sustainable
dividend policy - Payout < 100% |
- 6 -
Eni Fact Book Main data
Main data
Key financial data (a) |
2005 |
2006 |
2007 |
2008 |
2009 |
2010 |
2011 |
2012 |
2013 |
2014 |
Net sales from operations | 73,692 | 86,071 | 87,204 | 108,082 | 83,227 | 98,523 | 109,589 | 128,481 | 114,697 | 109,847 | |||||||||||||||||||||
of which: continuing operations | 106,978 | 81,932 | 96,617 | 107,690 | 127,109 | 114,697 | 109,847 | ||||||||||||||||||||||||
Group operating profit | 16,664 | 19,336 | 18,739 | 18,517 | 12,055 | 16,111 | 17,435 | 16,099 | 8,888 | 7,917 | |||||||||||||||||||||
Special items | (1,210 | ) | 88 | (620 | ) | 2,034 | 1,295 | 2,290 | 1,567 | 4,743 | 3,046 | 2,197 | |||||||||||||||||||
Profit (loss) on stock | 1,942 | 1,059 | 885 | 936 | (345 | ) | (881 | ) | (1,113 | ) | (17 | ) | 716 | 1,460 | |||||||||||||||||
Group adjusted operating profit | 17,396 | 20,483 | 19,004 | 21,487 | 13,005 | 17,520 | 17,889 | 20,825 | 12,650 | 11,574 | |||||||||||||||||||||
Adjusted operating profit - continuing operations | 21,322 | 12,722 | 16,845 | 17,230 | 19,883 | 12,650 | 11,574 | ||||||||||||||||||||||||
Exploration & Production | 12,649 | 15,521 | 13,770 | 17,166 | 9,489 | 13,898 | 16,075 | 18,537 | 14,643 | 11,551 | |||||||||||||||||||||
Gas & Power | 3,783 | 4,117 | 4,414 | 1,778 | 2,022 | 1,268 | (247 | ) | 398 | (638 | ) | 310 | |||||||||||||||||||
Refining & Marketing | 1,210 | 794 | 292 | 555 | (381 | ) | (181 | ) | (539 | ) | (289 | ) | (457 | ) | (208 | ) | |||||||||||||||
Versalis | 261 | 219 | 116 | (382 | ) | (441 | ) | (96 | ) | (273 | ) | (483 | ) | (386 | ) | (346 | ) | ||||||||||||||
Engineering & Construction | 314 | 508 | 840 | 1,041 | 1,120 | 1,326 | 1,443 | 1,485 | (99 | ) | 479 | ||||||||||||||||||||
Other activities | (296 | ) | (299 | ) | (207 | ) | (244 | ) | (258 | ) | (205 | ) | (226 | ) | (222 | ) | (210 | ) | (178 | ) | |||||||||||
Corporate and financial companies | (384 | ) | (244 | ) | (195 | ) | (282 | ) | (342 | ) | (265 | ) | (266 | ) | (325 | ) | (332 | ) | (265 | ) | |||||||||||
Impact of unrealized intragroup profit elimination and consolidation adjustments | (141 | ) | (133 | ) | (26 | ) | 1,690 | 1,513 | 1,100 | 1,263 | 782 | 129 | 231 | ||||||||||||||||||
Adjusted operating profit - discontinued operations | 165 | 283 | 675 | 659 | 942 | ||||||||||||||||||||||||||
Group net profit (*) | 8,788 | 9,217 | 10,011 | 8,825 | 4,367 | 6,318 | 6,860 | 7,790 | 5,160 | 1,291 | |||||||||||||||||||||
of which: continuing operations | 8,996 | 4,488 | 6,252 | 6,902 | 4,200 | 5,160 | 1,291 | ||||||||||||||||||||||||
of which: discontinued operations | (171 | ) | (121 | ) | 66 | (42 | ) | 3,590 | |||||||||||||||||||||||
Group adjusted net profit (*) | 9,251 | 10,401 | 9,569 | 10,164 | 5,207 | 6,869 | 6,969 | 7,325 | 4,430 | 3,707 | |||||||||||||||||||||
of which: continuing operations | 10,315 | 5,321 | 6,770 | 6,938 | 7,130 | 4,430 | 3,707 | ||||||||||||||||||||||||
of which: discontinued operations | (151 | ) | (114 | ) | 99 | 31 | 195 | ||||||||||||||||||||||||
Net cash provided by operating activities | 14,936 | 17,001 | 15,517 | 21,801 | 11,136 | 14,694 | 14,382 | 12,567 | 11,026 | 15,110 | |||||||||||||||||||||
of which: continuing operations | 21,506 | 10,755 | 14,140 | 13,763 | 12,552 | 11,026 | 15,110 | ||||||||||||||||||||||||
of which: discontinued operations | 295 | 381 | 554 | 619 | 15 | ||||||||||||||||||||||||||
Capital expenditure | 7,414 | 7,833 | 10,593 | 14,562 | 13,695 | 13,870 | 13,438 | 13,561 | 12,800 | 12,240 | |||||||||||||||||||||
of which: continuing operations | 12,935 | 12,216 | 12,450 | 11,909 | 12,805 | 12,800 | 12,240 | ||||||||||||||||||||||||
of which: discontinued operations | 1,627 | 1,479 | 1,420 | 1,529 | 756 | ||||||||||||||||||||||||||
Shareholders equity including non-controlling interest | 39,217 | 41,199 | 42,867 | 48,510 | 50,051 | 55,728 | 60,393 | 62,417 | 61,049 | 62,209 | |||||||||||||||||||||
Net borrowings | 10,475 | 6,767 | 16,327 | 18,376 | 23,055 | 26,119 | 28,032 | 15,069 | 14,963 | 13,685 | |||||||||||||||||||||
Leverage | 0.27 | 0.16 | 0.38 | 0.38 | 0.46 | 0.47 | 0.46 | 0.24 | 0.25 | 0.22 | |||||||||||||||||||||
Net capital employed | 49,692 | 47,966 | 59,194 | 66,886 | 73,106 | 81,847 | 88,425 | 77,486 | 76,012 | 75,894 | |||||||||||||||||||||
Exploration & Production | 19,109 | 17,783 | 23,826 | 31,362 | 32,455 | 37,646 | 42,024 | 42,369 | 45,699 | 47,629 | |||||||||||||||||||||
Gas & Power | 20,075 | 19,713 | 21,333 | 9,636 | 11,024 | 12,931 | 12,367 | 10,597 | 9,201 | 7,776 | |||||||||||||||||||||
Snam | 11,918 | 13,730 | 14,415 | 15,393 | |||||||||||||||||||||||||||
Refining & Marketing | 5,993 | 5,631 | 7,675 | 7,379 | 8,105 | 8,321 | 9,188 | 8,871 | 7,998 | 7,993 | |||||||||||||||||||||
Versalis | 2,018 | 1,953 | 2,228 | 1,915 | 1,774 | 1,978 | 2,252 | 2,557 | 2,656 | 2,973 | |||||||||||||||||||||
Engineering & Construction | 2,844 | 3,399 | 4,313 | 5,022 | 6,566 | 7,610 | 8,217 | 9,937 | 9,554 | 8,644 | |||||||||||||||||||||
Corporate financial companies and other activities | 2 | (95 | ) | 294 | 24 | (192 | ) | (527 | ) | (393 | ) | 3,658 | 1,381 | 1,089 | |||||||||||||||||
Impact of unrealized intragroup profit elimination | (349 | ) | (418 | ) | (475 | ) | (370 | ) | (356 | ) | (527 | ) | (623 | ) | (503 | ) | (477 | ) | (210 | ) | |||||||||||
(a)
Following the divestment of Regulated Businesses in
Italy, results of Snam have been accounted as
"discontinued operations". Results for the
2008-2011 period have been restated accordingly. (*) Attributable to Enis shareholders. |
Key market indicators |
2005 |
2006 |
2007 |
2008 |
2009 |
2010 |
2011 |
2012 |
2013 |
2014 |
Average price of Brent dated crude oil (a) | 54.38 | 65.14 | 72.52 | 96.99 | 61.51 | 79.47 | 111.27 | 111.58 | 108.66 | 98.99 | |||||||||||||
Average EUR/USD exchange rate (b) | 1.244 | 1.256 | 1.371 | 1.471 | 1.393 | 1.327 | 1.392 | 1.285 | 1.328 | 1.329 | |||||||||||||
Average price in euro of Brent dated crude oil | 43.71 | 51.86 | 52.90 | 65.93 | 44.16 | 59.89 | 79.94 | 86.83 | 81.82 | 74.48 | |||||||||||||
Standard Eni Refining Margin (SERM) (c) | n.a. | 6.37 | 7.20 | 8.45 | 3.11 | 3.06 | 1.82 | 4.12 | 2.43 | 3.21 | |||||||||||||
Euribor - three-month euro rate | (%) | 2.2 | 3.1 | 4.3 | 4.6 | 1.2 | 0.8 | 1.4 | 0.6 | 0.2 | 0.2 | ||||||||||||
(a) In USD
per barrel. Source: Platts Oilgram. (b) Source: ECB. (c) In USD per barrel FOB Mediterranean Brent dated crude oil. Source: Eni calculations. Approximates the margin of Enis refining system in consideration of material balances and refineries product yields. |
- 7 -
Eni Fact Book Main data |
Selected operating data |
2005 |
2006 |
2007 |
2008 |
2009 |
2010 |
2011 |
2012 |
2013 |
2014 |
Corporate (a) | |||||||||||||||||||||||
Employees at period end | (number) | 71,773 | 72,850 | 75,125 | 71,714 | 71,461 | 73,768 | 72,574 | 79,405 | 83,887 | 84,405 | ||||||||||||
of which: - women | 10,620 | 10,841 | 10,977 | 11,611 | 11,955 | 12,161 | 12,542 | 12,847 | 13,588 | 13,650 | |||||||||||||
of which: - outside Italy | 34,036 | 35,818 | 38,634 | 41,971 | 42,633 | 45,967 | 45,516 | 52,008 | 56,509 | 58,182 | |||||||||||||
Female managers | (%) | 12.4 | 13.5 | 14.1 | 16.3 | 17.3 | 18.0 | 18.5 | 18.9 | 19.4 | 19.7 |
Employee injury frequency rate | (number of injuries/million of worked hours) | 2.74 | 2.45 | 1.93 | 1.22 | 0.84 | 0.80 | 0.65 | 0.57 | 0.40 | 0.38 | ||||||||||||
Contractor injury frequency rate | 2.59 | 1.54 | 1.45 | 1.09 | 0.97 | 0.71 | 0.57 | 0.45 | 0.32 | 0.26 | |||||||||||||
Fatality index | (fatal injuries per one hundred millions of worked hours) | 3.38 | 2.31 | 2.97 | 2.75 | 1.20 | 4.77 | 1.94 | 1.10 | 0.98 | 0.72 |
Oil spills | (barrel) | 6,908 | 6,151 | 6,731 | 4,749 | 6,259 | 4,269 | 7,295 | 3,759 | 1,901 | 1,179 | ||||||||||||
GHG emission (GHG) | (mmtonnes CO2 eq) | 61.85 | 60.72 | 67.25 | 59.59 | 55.49 | 58.26 | 49.13 | 52.84 | 47.60 | 42.93 |
R&D expenditures (b) | (euro million) | 204 | 222 | 208 | 211 | 233 | 218 | 190 | 211 | 197 | 186 | ||||||||||||
Exploration & Production | |||||||||||||||||||||||
Proved reserves of hydrocarbons at period end | (mmboe) | 6,837 | 6,436 | 6,370 | 6,600 | 6,571 | 6,843 | 7,086 | 7,166 | 6,535 | 6,602 | ||||||||||||
Reserve life index | (years) | 10.8 | 10.0 | 10.0 | 10.0 | 10.2 | 10.3 | 12.3 | 11.5 | 11.1 | 11.3 | ||||||||||||
Hydrocarbons production | (kboe/d) | 1,737 | 1,770 | 1,736 | 1,797 | 1,769 | 1,815 | 1,581 | 1,701 | 1,619 | 1,598 | ||||||||||||
Gas & Power | |||||||||||||||||||||||
Sales of consolidated companies (including own consumption) | (bcm) | 82.62 | 85.76 | 84.83 | 89.32 | 89.60 | 82.00 | 84.05 | 84.30 | 83.60 | 81.73 | ||||||||||||
Sales of Enis affiliates (Enis share) | 7.08 | 7.65 | 8.74 | 8.91 | 7.95 | 9.41 | 9.85 | 8.29 | 6.96 | 4.38 | |||||||||||||
Total sales and own consumption (G&P) | 89.70 | 93.41 | 93.57 | 98.23 | 97.55 | 91.41 | 93.90 | 92.59 | 90.56 | 86.11 | |||||||||||||
E&P sales in Europe and in the Gulf of Mexico | 4.51 | 4.69 | 5.39 | 6.00 | 6.17 | 5.65 | 2.86 | 2.73 | 2.61 | 3.06 | |||||||||||||
Worldwide gas sales | 94.21 | 98.10 | 98.96 | 104.23 | 103.72 | 97.06 | 96.76 | 95.32 | 93.17 | 89.17 | |||||||||||||
Electricity sold | (TWh) | 27.56 | 31.03 | 33.19 | 29.93 | 33.96 | 39.54 | 40.28 | 42.58 | 35.05 | 33.58 | ||||||||||||
Refining & Marketing | |||||||||||||||||||||||
Throughputs on own account | (mmtonnes) | 38.79 | 38.04 | 37.15 | 35.84 | 34.55 | 34.80 | 31.96 | 30.01 | 27.38 | 25.03 | ||||||||||||
Balanced capacity of wholly-owned refineries | (kbbl/d) | 524 | 534 | 544 | 737 | 747 | 757 | 767 | 767 | 787 | 617 | ||||||||||||
Sales of refined products | (mmtonnes) | 51.63 | 51.13 | 50.15 | 49.16 | 45.59 | 46.80 | 45.02 | 48.33 | 43.49 | 44.41 | ||||||||||||
Retail sales in Europe | (mmtonnes) | 12.42 | 12.48 | 12.65 | 12.03 | 12.02 | 11.73 | 11.37 | 10.87 | 9.69 | 9.21 | ||||||||||||
Service stations at year end | (units) | 6,282 | 6,294 | 6,440 | 5,956 | 5,986 | 6,167 | 6,287 | 6,384 | 6,386 | 6,220 | ||||||||||||
Average throughput per service station | (kliters/y) | 2,479 | 2,470 | 2,486 | 2,502 | 2,477 | 2,352 | 2,206 | 2,064 | 1,828 | 1,725 | ||||||||||||
Versalis | |||||||||||||||||||||||
Production | (ktonnes) | 7,282 | 7,072 | 8,795 | 7,372 | 6,521 | 7,220 | 6,245 | 6,090 | 5,817 | 5,283 | ||||||||||||
of which: - Intermediates | 4,450 | 4,275 | 5,688 | 5,110 | 4,350 | 4,860 | 4,101 | 3,595 | 3,462 | 2,972 | |||||||||||||
of which: - Polymers | 2,832 | 2,797 | 3,107 | 2,262 | 2,171 | 2,360 | 2,144 | 2,495 | 2,355 | 2,311 | |||||||||||||
Average plant utilization rate | (%) | 78.4 | 76.4 | 80.6 | 68.6 | 65.4 | 72.9 | 65.3 | 66.7 | 65.3 | 71.3 | ||||||||||||
Engineering & Construction | |||||||||||||||||||||||
Orders acquired | (euro million) | 8,395 | 11,172 | 11,845 | 13,860 | 9,917 | 12,935 | 12,505 | 13,391 | 10,062 | 17,971 | ||||||||||||
Order backlog at year end | (euro million) | 10,122 | 13,191 | 15,390 | 19,105 | 18,370 | 20,505 | 20,417 | 19,739 | 17,065 | 22,147 | ||||||||||||
(a) Following the
divestment of Regulated Businesses in Italy, data for the
year 2012 do not include Snam contribution. Results for
the 2008-2011 period have been restated accordingly. (b) Net of general and administrative costs. |
Share data |
2005 |
2006 |
2007 |
2008 |
2009 |
2010 |
2011 |
2012 |
2013 |
2014 |
Net profit (a) (b) | (euro) | 2.34 | 2.49 | 2.73 | 2.43 | 1.21 | 1.74 | 1.89 | 1.16 | 1.42 | 0.36 | ||||||||||||||
Net profit - continuing operations (a) (b) (*) | 2.47 | 1.24 | 1.72 | 1.90 | 1.16 | 1.42 | 0.36 | ||||||||||||||||||
Dividend | 1.10 | 1.25 | 1.30 | 1.30 | 1.00 | 1.00 | 1.04 | 1.08 | 1.10 | 1.12 | |||||||||||||||
Cash dividends (c) | (euro million) | 4,086 | 4,594 | 4,750 | 4,714 | 3,622 | 3,622 | 3,695 | 3,840 | 3,949 | 4,006 | ||||||||||||||
Cash flow | (euro) | 3.97 | 4.59 | 4.23 | 5.99 | 3.07 | 4.06 | 3.97 | 3.41 | 3.52 | 4.18 | ||||||||||||||
Dividend yield (d) | (%) | 4.7 | 5.0 | 5.3 | 7.6 | 5.8 | 6.1 | 6.6 | 5.9 | 6.5 | 7.6 | ||||||||||||||
Net profit per ADR (e) (*) | (USD) | 5.81 | 6.26 | 7.49 | 7.27 | 3.45 | 4.56 | 5.29 | 2.98 | 3.77 | 0.96 | ||||||||||||||
Dividend per ADR (e) | 2.73 | 3.14 | 3.74 | 3.72 | 2.91 | 2.64 | 2.73 | 2.82 | 3.00 | 2.79 | |||||||||||||||
Cash flow per ADR (e) | 9.40 | 11.53 | 11.60 | 17.63 | 8.56 | 10.77 | 11.05 | 8.77 | 9.04 | 11.12 | |||||||||||||||
Dividend yield per ADR (d) | (%) | 4.7 | 4.7 | 5.2 | 8.1 | 5.8 | 6.1 | 6.6 | 5.9 | 6.4 | 7.7 | ||||||||||||||
Pay-out | 46 | 50 | 47 | 53 | 81 | 57 | 55 | 50 | 77 | 311 | |||||||||||||||
Number of shares at period end representing share capital | (million) | 4,005.4 | 4,005.4 | 4,005.4 | 4,005.4 | 4,005.4 | 4,005.4 | 4,005.4 | 3,634.2 | 3,634.2 | 3,634.2 | ||||||||||||||
Average number of share outstanding in the year (f) (fully diluted) | 3,763.4 | 3,701.3 | 3,669.2 | 3,638.9 | 3,622.4 | 3,622.5 | 3,622.7 | 3,622.8 | 3,622.8 | 3,610.4 | |||||||||||||||
TSR | (%) | 35.3 | 14.8 | 3.2 | (29.1 | ) | 13.7 | (2.2 | ) | 5.1 | 22.0 | 1.3 | (11.9 | ) |
(*) Following the
divestment of Regulated Businesses in Italy, results of
Snam have been accounted for as "discontinued
operations", based on IFRS 5. Results for the
2008-2011 period have been restated accordingly. Net
profit refers to results of continuing operations as
reported in Eni consolidated Annual Report. (a) Calculated on the average number of Eni shares outstanding during the year. (b) Pertaining to Enis shareholders. (c) Pertaining to the year. The amount for the year 2014 is based on the Boards proposal. (d) Ratio between dividend of the year and average share price in December. (e) One ADR represents 2 shares. Net profit, dividends and cash flow data were converted using average exchange rates. Dividends data were converted at the Noon Buying Rate of the pay-out date. (f) Calculated by excluding own shares in portfolio. |
- 8 - |
Eni Fact Book Main data
Share information |
2005 |
2006 |
2007 |
2008 |
2009 |
2010 |
2011 |
2012 |
2013 |
2014 |
Share price - Milan Stock Exchange | |||||||||||||||||||||||
High | (euro) | 24.96 | 25.73 | 28.33 | 26.93 | 18.35 | 18.56 | 18.42 | 18.70 | 19.48 | 20.41 | ||||||||||||
Low | 17.93 | 21.82 | 22.76 | 13.80 | 12.30 | 14.61 | 12.17 | 15.25 | 15.29 | 13.29 | |||||||||||||
Average | 21.60 | 23.83 | 25.10 | 21.43 | 16.59 | 16.39 | 15.95 | 17.18 | 17.57 | 17.83 | |||||||||||||
End of the period | 23.43 | 25.48 | 25.05 | 16.74 | 17.80 | 16.34 | 16.01 | 18.34 | 17.49 | 14.51 | |||||||||||||
ADR price (a) - New York Stock Exchange | |||||||||||||||||||||||
High | (USD) | 151.35 | 67.69 | 78.29 | 84.14 | 54.45 | 53.89 | 53.74 | 49.44 | 52.12 | 55.30 | ||||||||||||
Low | 118.50 | 54.65 | 60.22 | 37.22 | 31.07 | 35.37 | 32.98 | 36.85 | 40.39 | 32.81 | |||||||||||||
Average | 134.02 | 59.97 | 68.80 | 63.38 | 46.36 | 43.56 | 44.41 | 44.24 | 46.68 | 47.37 | |||||||||||||
End of the period | 139.46 | 67.28 | 72.43 | 47.82 | 50.61 | 43.74 | 41.27 | 49.14 | 48.49 | 34.91 | |||||||||||||
Average daily exchanged shares | (million of shares) | 28.5 | 26.2 | 30.5 | 28.7 | 27.9 | 20.7 | 22.9 | 15.6 | 15.4 | 17.21 | ||||||||||||
Value | (euro million) | 620.7 | 619.1 | 773.1 | 610.4 | 461.7 | 336.0 | 355.0 | 267.0 | 271.4 | 304.0 | ||||||||||||
Weighted average number of shares outstanding (b) | (million) | 3,727.3 | 3,680.4 | 3,656.8 | 3,622.4 | 3,622.4 | 3,622.7 | 3,622.7 | 3,622.8 | 3,622.8 | 3,610.4 | ||||||||||||
Market capitalization (c) | |||||||||||||||||||||||
EUR | (billion) | 87.3 | 93.8 | 91.6 | 60.6 | 64.5 | 59.2 | 58.0 | 66.4 | 63.4 | 52.4 | ||||||||||||
USD | 104.0 | 123.8 | 132.4 | 86.6 | 91.7 | 79.2 | 75.0 | 87.7 | 87.4 | 63.6 | |||||||||||||
(a) Effective January 10,
2006 a 5:2 stock split was made. Previous periods
prices have not been restated. (b) Excluding treasury shares. (c) Number of outstanding shares by reference price at period end. |
Data on Eni share placement |
1995 |
1996 |
1997 |
1998 |
2001 |
Offer price | (euro/share) | 5.42 | 7.40 | 9.90 | 11.80 | 13.60 | ||||||
Number of share placed | (million shares) | 601.9 | 647.5 | 728.4 | 608.1 | 200.1 | ||||||
of which: through bonus share | (million shares) | 1.9 | 15.0 | 24.4 | 39.6 | |||||||
Percentage of share capital (a) | (%) | 15.0 | 16.2 | 18.2 | 15.2 | 5.0 | ||||||
Proceeds | (euro million) | 3,254 | 4,596 | 6,869 | 6,714 | 2,721 | ||||||
(a) Refers to share capital at December 31, 2014. |
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Eni Fact Book Eni's business model
Enis business model |
Enis business model targets long-term value creation for its stakeholders by delivering on profitability and growth, efficiency and operational excellence and handling operational risks of its businesses, as well as environmental conservation, and local communities relationships, preserving health and safety of people working in Eni and with Eni, in respect of human rights, ethics and transparency. The main capitals used by Eni (financial capital, productive capital, intellectual capital, natural capital, human | capital, social and
relationship capital) are classified in accordance with
the criteria included in the "International IR
Framework" published by the International Integrated
Reporting Council (IIRC). 2014 financial results and
sustainability performance rely on the responsible and
efficient use of our capitals. For detailed information on results associated to each capital see the 2014 Integrated Annual Report and the Integrated performance tables. |
- 10 -
Eni Fact Book Eni's business model
Hereunder is articulated the
map of the main capitals exploited by Eni and actions
taken in order to achieve the 2015-2018 targets for each
business area. The actions reported below are classified on the basis of four |
strategic targets which lead Enis business and represent the management system of each capital which allow to achieve business goals, on the one hand reducing risks, on the other, increasing profitability. |
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Eni Fact Book Exploration & Production
Exploration & Production |
Key performance indicators |
2010 |
2011 |
2012 |
2013 |
2014 |
||||||||
Injury frequency rate of total Eni workforce | (No. of accidents per million of worked hours) | 0.53 | 0.41 | 0.34 | 0.23 | 0.23 | ||||||
Net sales from operations (a) | (euro million) | 29,497 | 29,121 | 35,874 | 31,264 | 28,488 | ||||||
Operating profit | 13,866 | 15,887 | 18,470 | 14,868 | 10,766 | |||||||
Adjusted operating profit | 13,898 | 16,075 | 18,537 | 14,643 | 11,551 | |||||||
Adjusted net profit | 5,609 | 6,865 | 7,426 | 5,950 | 4,423 | |||||||
Capital expenditure | 9,690 | 9,435 | 10,307 | 10,475 | 10,524 | |||||||
Adjusted ROACE | (%) | 16.0 | 17.2 | 17.6 | 13.5 | 9.5 | ||||||
Profit per boe (b) | ($/boe) | 11.9 | 17.0 | 16.0 | 15.5 | 9.9 | ||||||
Opex per boe (b) | 6.1 | 7.3 | 7.1 | 8.3 | 8.4 | |||||||
Cash Flow per boe (d) | 25.5 | 31.7 | 32.8 | 31.9 | 30.1 | |||||||
Finding & Development cost per boe (c) (d) | 19.3 | 18.8 | 17.4 | 19.2 | 21.5 | |||||||
Average hydrocarbons realizations (d) | 55.60 | 72.26 | 73.39 | 71.87 | 65.49 | |||||||
Production of hydrocarbons(d) | (kboe/d) | 1,815 | 1,581 | 1,701 | 1,619 | 1,598 | ||||||
Estimated net proved reserves of hydrocarbons (d) | (mmboe) | 6,843 | 7,086 | 7,166 | 6,535 | 6,602 | ||||||
Reserves life index (d) | (years) | 10.3 | 12.3 | 11.5 | 11.1 | 11.3 | ||||||
Organic reserves replacement ratio (d) | (%) | 127 | 143 | 147 | 105 | 112 | ||||||
Employees at year end | (number) | 10,276 | 10,425 | 11,304 | 12,352 | 12,777 | ||||||
of which: outside Italy | 6,370 | 6,628 | 7,371 | 8,219 | 8,243 | |||||||
Oil spills due to operations (>1 barrel) (e) | (bbl) | 3,820 | 2,930 | 3,015 | 1,728 | 936 | ||||||
Produced water re-injected | (%) | 44 | 43 | 49 | 55 | 56 | ||||||
Direct GHG emissions | (mmtonnes CO2 eq) | 31.46 | 23.78 | 28.68 | 25.90 | 22.98 | ||||||
of which: from flaring | 13.83 | 9.55 | 9.46 | 8.48 | 5.64 | |||||||
Community investment | (euro million) | 72 | 62 | 59 | 53 | 63 | ||||||
(a) Before
elimination of intragroup sales. (b) Consolidated subsidiaries. (c) Three-year average. (d) Includes Enis share of equity-accounted entities. (e) 2010 and 2011 data include also oil spills less than 1 barrel. |
Performance of the year | ||
I In 2014, the injury frequency rate
confirmed the positive performance reported in 2013. - Greenhouse gas emissions decreased by 11.3% compared to the previous year (with a 33.5% reduction in emissions from flaring) mainly due to the conclusion of the flaring down project at MBoundi field in Congo and the ramp-up of relevant projects in Nigeria. - Oil spills reported a decline from 2013 (with a 46% decrease in oil spills due to operations), while zero blow-outs were recorded for the eleventh consecutive year. - Continued a positive trend in increasing water reinjection, with a record level of 56%, due among other to the completion of relevant projects, in particular in Nigeria, Egypt, Indonesia and Turkmenistan. - In 2014, the E&P segment reported a decline of euro 1,527 million, or 25.7% in adjusted net profit compared to a year ago, due to lower crude oil and gas prices in dollar terms (down by 8.9% on average) reflecting the fall of Brent crude benchmark and the weakness of gas market, especially in Europe. - Oil and natural gas production was 1.598 million boe/d in 2014 (up |
by 0.6% compared to the
previous year), excluding the impact of the divestment of
Enis interest in Siberian assets. - Estimated net proved reserves at December 31, 2014 amounted to 6.6 bboe based on a reference Brent price of $101 per barrel. The reserves replacement ratio was 112%. The reserves life index was 11.3 years (11.1 years in 2013). Exploration activity I Eni continued its track record of
exploratory success. Additions to the Companys
reserve backlog were approximately 900 million boe of
resources for the full year, at a competitive cost of
$2.1 per barrel. Near-field discoveries marked the
years activity: |
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Eni Fact Book Exploration & Production
- The Minsala Marine 1 NFW
in the conventional waters of Block Marine XII (Eni
operator with a 65% interest) in Congo, was the third
discovery in the last two years increasing the
blocks resources in place by 1 billion barrels with
characteristics similar to the previous discoveries of
Litchendjili and Nené, the latter started up early
production in record time. - The Oglan-2 exploration well in Block 10 (Eni operator with a 100% interest), in Ecuador, with a potential in place estimated at approximately 300 million barrels of oil. The discovery is located near the processing facilities of the operated field of Villano and will be put in production with fast-track development. - The Merakes 1 NFW gas well in East Sepinggan offshore block (Eni operator with a 85% interest), in Indonesia. This discovery with a potential in place estimated at approximately 2 Tcf, is located in proximity of the operated field of Jangkrik (Enis interest 55%), which is currently under development and will supply additional gas volumes to the Bontang LNG plant. - The conventional waters of Gabon, the Nyonie Deep 1 well in the Block D4 (Eni operator with a 100% interest) showed an estimated potential of approximately 500 million boe in place of gas and condensates. - The appraisal gas wells Agulha 2 and Coral 4 DIR, confirming the extension of their respective fields with a potential in place in Area 4 (Eni operator with a 50% interest) estimated at approximately 88 Tcf. - The exploration portfolio was strengthened by means of new exploration acreage covering approximately 100,000 square kilometers net to Eni in the high potential areas such as Myanmar, Portugal, South Africa and Vietnam, as well as legacy areas such as Algeria, China, Egypt, Norway, the United Kingdom and the United States. - In 2014, exploration expenditure amounted to euro 1,398 million, mainly related to the completion of 44 new exploratory wells (25.8 net to Eni). The overall commercial success rate was 31.3% (38.0% net to Eni). In addition, 101 exploratory wells drilled are in progress at year end (42.2 net to Eni). Sustainability
and portfolio I The West Hub Development project in Block 15/06 (Eni operator with a 35% interest) achieved the first oil late in 2014. This is the first Eni- |
operated project in Angola
and is currently flowing at 45 kbbl/d, with production
ramp-up expected to reach a plateau of up to 100 kbbl/d
in the coming months. The start-up was achieved in just
44 months from the announcement of the commercial
discovery, a result that is at the top of the industry
among deep waters developments. - Production start-up achieved at the recent Nené discovery in Block Marine XII (Eni operator with a 65% interest) in Congo, just 8 months after obtaining the production permit. The early production phase is yielding 7.5 kboe/d and the fast-track development of the field has leveraged on the synergies with the front-end loading and the infrastructures of the fields located in the area. The full-field development will take place in several stages, with a plateau of over 120 kboe/d. - Sanctioned the integrated oil and gas project of the Offshore Cape Three Points (Eni operator with a 47.22% interest) in Ghana. First oil is expected in 2017, first gas in 2018 and production is expected to peak at 80 kboe/d. - Projects to promote local development and to support local communities progressed with programs in educational services, improving sanitary condition, access to water, socio-economic development activities, in particular in Congo, Ecuador, Indonesia, Iraq, Italy, Kazakhstan, Mozambique, Nigeria and Norway. In addition, the construction of educational facilities and programs of access to water were performed in Pakistan, projects of employment and local business development in particular in Tunisia and Australia, as well as activities of enhancement of cultural and environmental heritage. - The Petroleum Technology Association of Nigeria recognized two Enis subsidiaries as the best organizations to promote local content in the oil&gas sector in Nigeria (Local Content Operator). This award reaffirmed Enis commitment in the implementation of effective initiatives to boost local economic activities also to achieve the high standard requirements in the oil&gas sector. - Performed with the support of the Danish Institute for Human Rights and in line with the UN Guiding Principles on Business and Human Rights a preliminary assessment of the potential impacts of natural gas development on human rights in Mozambique. - Development expenditure was euro 9,021 million (up by 5.1% from 2013) to fuel the growth of major projects and to maintain production plateau particularly in Norway, Angola, Congo, the United States, Italy, Nigeria, Egypt, Indonesia and Kazakhstan. - In 2014, overall R&D expenditure of the Exploration & Production segment amounted to euro 83 million (euro 87 million in 2013). |
Strategy | ||
Upstream growth model
will continue to focus on conventional assets, which will
be organically developed, with a large resource base and
a competitive cost structure, which make them profitable
even in a low price environment. The sizeable exploration successes of the last years have increased the Companys resource base, contributing to the Companys value generation through the early monetization of the discovered resources in excess of the target replacement ratio. Enis top priorities are the increase and valorization of discovered resources and a growing cash generation. The drivers to target the increase and valorization of discovered resources are: (i) re-balancing of exploration activities with a focus on near-field initiatives, with the objective of delivering 2 billion boe of discovered resources at a competitive cost of $2.6 per bbl; (ii) renewal of the portfolio of exploration leases by focusing on high materiality play; and (iii) fast-track development of discovered resources by optimizing the time-to-market and exercising tight control on project execution. Cash generation will be driven by: (i) production growth at an annual rate of 3.5% leveraging on a robust pipeline of projects with an average break-even of $45 per bbl which together with the ramp-ups at fields started up in 2014 will add more than 650 kboe/d in 2018. This new production |
- 13 -
Eni Fact Book Exploration & Production
will bring an additional cumulative
cash flow of euro 19 billion in the 2015-2018 plan
period. Main start-ups are the Goliat field (Eni operator
with a 65% interest) in the Barents Sea in Norway, the
oil and gas project of Offshore Cape Three Points (Eni
operator with a 47.22% interest) in Ghana, the Jangkrik
project (Eni operator with a 55% interest) in Indonesia
and production re-start of Kashagan field (Enis
interest 16.81%) by the end of 2016; (ii) project
modularization and phasing which will enable the Company
to reduce financial exposure and to accelerate production
start-ups; (iii) strengthened efficiency by means of
several initiatives to reduce operating costs, to be
achieved also by renegotiating the supply of field
services and goods; and (iv) early monetization of part
of discovered volumes. Eni acknowledges that the upstream performance could be adversely impacted in the short-to-medium term by a number of risks: (i) the commodity risk related to current trends in crude oil prices. Eni is planning to mitigate this risk by implementing initiatives of rationalization and optimization, the renegotiation of contractual terms with contractors to align costs of field services and goods to the changed market conditions. In 2015-2018 plan period, Eni estimates a decrease of approximately 13% of capital expenditure net of exchange rate effects versus the previous four year plan due to a reduction in exploration expenditure which will be focused on near-field and appraisal activities, the re-phasing of projects yet to be sanctioned and service contract renegotiations. In addition, Eni intends to reduce operating costs by 7% versus the old plan; (ii) the political risk due to social and political instability in certain countries of operations. A major part of Enis activities are currently located in countries that are far from high-risk areas and Eni plans to growth mainly in countries with low-mid political risk (approximately 90% of the capital expenditure of the four-year plan); (iii) risk related to the growing complexity of certain projects due to technological and logistic issues. Eni plans to counteract those risks by strict selection of adequate contractors, tight control of the time-to-market and the retaining of the operatorship in a large number of projects (84% of production related to start-ups); and (iv) the technical risk related to the execution of drilling activities at high pressure/high temperature wells and deep waters wells (24% of planned wells to be drilled in 2015). Eni plans to increase operatorship of critical projects ensuring better direct control and deploying its high operational standards. |
Activity areas
n Italy Eni has been operating in Italy since 1926. In 2014, Enis oil and gas production amounted to 179 kboe/d. Enis activities in Italy are deployed in the Adriatic and Ionian Sea, the Central Southern Apennines, mainland and offshore Sicily and the Po Valley, on a total developed and undeveloped acreage of 21,463 square kilometers (17,297 square kilometers net to Eni). Enis exploration and development activities in Italy are regulated by concession contracts (54 operated onshore and 64 operated offshore) and exploration licenses (12 onshore and 9 offshore). |
Adriatic and Ionian Sea Production Fields in the Adriatic and Ionian Sea accounted for 46% of Enis domestic production in 2014, mainly gas. Main operated fields are Barbara, Annamaria, Angela-Angelina, Porto Garibaldi, Cervia, Bonaccia, Luna and Hera Lacinia. Production is operated by means of 71 fixed platforms (3 of these are manned) installed on the main fields, to which satellite fields are linked by underwater infrastructures. Production is carried by sealine to the mainland where it is input in the national gas network. The system is subject |
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Eni Fact Book Exploration & Production
continuously to rigorous
safety control, maintenance activities and production
optimization, in particular at the Barbara, Armida,
Cervia, Clara, Arianna, Regina and Torrente Tona fields. Development Main development activities concerned the completion of development activities to achieve start-up of the Fauzia and Elettra fields located in the Adriatic Sea, as well as ongoing maintenance and efficiency improvement activities on Italian energetic grid. Ongoing activities progressed to perform the environmental monitoring, protection and clean-up of the Adriatic coastal area in cooperation with the district of Ravenna. Exploration Exploration activities concerned areas nearby producing fields with identification of possible near field opportunities. Central Southern Apennines Sicily n Rest of Europe Norway Norwegian Sea |
interest 14.9%), Tyrihans (Enis interest 6.2%),
Marulk (Eni operator with a 20% interest) and Morvin
(Enis interest 30%) which in 2014 accounted for 74%
of Enis production in Norway. The gas produced in
the area is collected at the Åsgard facilities, carried
by pipeline to the Karsto treatment plant and then
delivered to the Dornum terminal in Germany. Liquids
recovered in the area mainly through FPSO units are sold
FOB. Norwegian section of the North Sea |
- 15 -
Eni Fact Book Exploration & Production
Barents Sea |
cultural heritage of Sami
local community and of technical and professional skills
development of local communities. Exploration Exploration activities yielded positive results with the oil and gas Drivis discovery made at the offshore license PL 532 (Eni 30%), with volumes in place estimated in a range of 125 to 140 million barrels. The discovery will be put into production with the recent oil and gas discoveries of Skrugard, Havis and Skavl by means of the development of the integrated Johan Castberg Hub. The total recoverable resources of the license are estimated at over 600 million barrels at 100%. In January 2015, Eni was awarded the operatorship and a 40% interest in the PL 806 license. United Kingdom |
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Eni Fact Book Exploration & Production
completion of the Phase 2
development program by means of the installation of
production platform and pipeline connection to the
treatment facility in the area; and (ii) production
ramp-up of the Jasmine project (Enis interest 33%)
with the completion of commissioning and start-up of 4
additional production wells. Exploration Eni holds interests in 11 exploration blocks ranging from 7% to 50%, in 2 of these Eni is operator. Exploration activities yielded positive results with the Romeo North discovery, already linked to the production platform of the Jade field. During the year Eni was awarded the operatorship of the 22/19c (Enis interest 50%), 22/19e (Enis interest 57.14%) and 30/1b (Enis interest 100%) exploration blocks in the North Sea. n North Africa Algeria Blocks 403a/d and Rom Nord Blocks 401a/402a Block 403 Block 404 |
Block 405 Production Main producing asset is the MLE-CAFC project which accounted for approximately 15% of Enis production in the Country in 2014. The natural gas treatment plant has a production and export capacity of 320 mmcf/d of gas, 15 kbbl/d of oil and condensates and 12 kbbl/d of LPG. Four export pipelines link it to the national grid system. Development Development and optimization activities progressed at the MLE-CAFC project. Activities include an additional oil phase with start-up expected in 2017, targeting a production plateau of approximately 33 kboe/d net to Eni. Block 208 Egypt |
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Eni Fact Book Exploration & Production
these large concessions
accounted for approximately 94% of Enis production
in the Country. In March 2015, Eni and the Egyptian Ministry of Petroleum and Mineral Resources signed a framework agreement to develop the oil and gas resources in the Country with an estimated investment of $5 billion at 100%. The investments, which will be utilized through the realization of projects to be implemented in the next 4 years, are directed to the development of 200 mm/bbl of oil and 1.3 Tcf of gas. In 2014, Eni was awarded: (i) the operatorship of the South-West Meleiha onshore exploration licenses (Enis interest 100%), nearby the Meleiha concession, and the Block 9 (Enis interest 100%) and Block 8 (Enis interest 50%) located in the deep offshore of the Mediterranean Sea. The closing was achieved in the early 2015 with the ratification of the relevant concession agreements; and (ii) the Shorouk concession (Enis interest 100%) in the deep offshore of the Mediterranean Sea. Exploration and production activities in Egypt are regulated by PSAs. Gulf of Suez |
Nile Delta North Port Said Production Production for the year amounted to approximately 30 kboe/d (approximately 24 kboe/d net to Eni), approximately 141 mmcf/d of natural gas and approximately 3 kbbl/d of condensates. Part of the production of this concession is supplied to the United Gas Derivatives Co (Enis interest 33.33%) with a treatment capacity of 1.3 bcf/d of natural gas and a yearly production of 380 ktonnes of propane, 305 ktonnes of LPG and 1.5 mmbbl of condensates. Development Ongoing development activities aimed at supporting current gas production. Baltim Ras el Barr El Temsah Western Desert |
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Eni Fact Book Exploration & Production
Libya Eni started operations in Libya in 1959. Developed and undeveloped acreage in Libya was 26,635 square kilometers (13,294 square kilometers net to Eni). Production activity is carried out in the Mediterranean Sea facing Tripoli and in the Libyan Desert area and includes six contract areas. Onshore contract areas are: (i) Area A consisting in the former concession 82 (Enis interest 50%); (ii) Area B, former concession 100 (Bu Attifel field) and the NC125 Block (Enis interest 50%); (iii) Area E with El Feel (Elephant) field (Enis interest 33.3%); and (iv) Area F with Block 118 (Enis interest 50%). Offshore contract areas are: (i) Area C with the Bouri oilfield (Enis interest 50%); and (ii) Area D with Blocks NC41 and NC169 (onshore) that feed the Western Libyan Gas Project (Enis interest 50%). In the exploration phase, Eni is operator of four onshore blocks in the Kufra area (186/1, 2, 3 & 4) and in the onshore contract Areas A, B and offshore Area D. The internal situation in Libya continues to represent an issue to Enis management. Following the internal conflict of 2011 and the fall of the regime, which forced the Company to shut down almost all its producing facilities including gas exports for a period of about 8 months, a period of social and political instability began which turned into disorders, strikes, protests and a resurgence of the internal conflict. These events jeopardized Enis ability to perform its industrial activity in safety, forcing the Company to interrupt its operations on certain occasions as precautionary measure. These events were fairly frequent in 2013 and sporadic in 2014. In 2014, Enis facilities in Libya produced on average 239 kboe/d, registering a small increase compared to 2013. In light of the recent developments in Libya, management decided to strengthen security measures at the Companys production installations and facilities in the Country. However, we did not suffer any significant production shutdowns in the first part of 2015. |
Exploration and production
activities in Libya are regulated by six Exploration and
Production Sharing contracts (EPSA). The licenses of
Enis assets in Libya expire in 2042 and 2047 for
oil and gas properties, respectively. Exploration activities yielded positive results with the B1-16/4 well in the Bahr Essalam South prospects in the offshore Area D that flowed at approximately 35 mmcf/d of natural gas and over 600 bbl/d of condensates in test production. Tunisia n Sub-Saharan Africa Angola |
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Eni Fact Book Exploration & Production
Block 0 Production Block 0 is divided into Areas A and B. In 2014, production from this block amounted to approximately 292 kbbl/d (approximately 29 kbbl/d net to Eni). Oil production from Area A, deriving mainly from the Takula, Malongo and Mafumeira fields amounted to approximately 18 kbbl/d net to Eni. Production of Area B derives mainly from the Bomboco, Kokongo, Lomba, NDola, Nemba and Sanha fields, and amounted to approximately 11 kbbl/d net to Eni. Development The main development activities performed in the year concerned: (i) the progress of the Nemba field project to reduce flaring gas. In 2015, once the project is completed, flared gas is expected to decrease by approximately 85% from current level; (ii) the Mafumeira Sul field (Enis interest 9.8%) with start-up expected in 2016. Infilling activities and near-field exploration are underway on the whole block in order to mitigate the natural field production decline. Exploration Exploration activities yielded positive results with the appraisal of the Pinda Fm discovery. Block 3 |
Block 14 Production In 2014, Development Areas in Block 14 produced approximately 122 kbbl/d (approximately 16 kbbl/d net to Eni), accounting for approximately 15% of Enis production in the Country. It is one of the most fruitful areas in the West African offshore, recording 9 commercial discoveries to date. Its main fields are Kuito, Landana and Tombua, as well as Benguela-Belize/Lobito-Tomboco. Associated gas of the area will be re-injected in the Nemba reservoir and later it will be delivered via a transport facility to the A-LNG liquefaction plant (see below). Development The main development activities performed in the year concerned the Lianzi project in the Block 14K/A Imi Unit Area (Enis interest 10%), with start-up expected in the second half of 2015 and production plateau of 35 kboe/d. Concept definition studies of Malange discovery are underway. Block 15 Block 15/06 |
- 20 -
Eni Fact Book Exploration & Production
In January 2015, Eni
obtained from the Angolan authorities a three-year
extension of the exploration period of the above
mentioned block. The LNG business in Angola Congo |
Production Enis
main operated oil producing interests in Congo are the
Zatchi (Enis interest 56%), Loango (Enis
interest 42.5%), Ikalou (Enis interest 100%),
Djambala (Enis interest 50%), Foukanda and Mwafi
(Enis interest 58%), Kitina (Enis interest
52%), Awa Paloukou (Enis interest 90%),
MBoundi (Enis interest 83%), Kouakouala
(Enis interest 75%), Zingali and Loufika
(Enis interest 100%) fields, with an overall
production of 76 kboe/d net to Eni. Other relevant
producing areas are a 35% interest in the Pointe-Noire
Grand Fond, PEX and Likouala permits with a production of
30 kboe/d net to Eni. At the end of December 2014 was achieved the start-up of the recent Nené Marine discovery in Block Marine XII (Eni operator with a 65% interest) just 8 months after obtaining the production permit. The early production phase is yielding 7,500 boe/d and the fast-track development of the field has leveraged on the synergies with the front-end loading and the infrastructures of the fields located in the area. The full-field development will take place in several stages and will include the installation of production platforms and the drilling of approximately 30 wells, with a plateau of over 120 kboe/d. Development The flaring down project of the MBoundi field was completed during the year with a decrease of approximately 64 mmcf in daily volumes of gas flaring, thus achieving the zero flaring target in the area. In particular, the associated gas was fully valorized through: (i) a program of gas injection in order to optimize reserve recovery; and (ii) a long-term supply contract to power plants in the area including the CEC Centrale Electrique du Congo plant (Enis interest 20%) with a 300 MW generation capacity. In 2014, MBoundi contractual supplies were approximately 106 mmcf/d (approximately 17 kboe/d net to Eni). These facilities will also receive volumes of gas from the offshore discoveries of the Block Marine XII in the future. Project Integrée Hinda (PIH) progressed to support the population in the MBoundi area. The social project provides to improve education, health, production capacity in agriculture with specific programs and in collaboration with local authorities. Planned activities for the 2011-2015 periods achieved a work progressing of 80% at the end of 2014. The program involved approximately 25,000 people. Eni with the support of the Earth Institute of the Columbia University launched a program to design a monitoring system to assess the effectiveness of the PIH project and to check its support to the development of the area. In addition, local cultural promotion programs started-up with specific activities in the Pointe-Noire area, Makoua, located in the north of the country and in the capital, Brazzaville. Development of the Litchendjili sanctioned project progressed in the Marine XII block. The project provides for the installation of a production platform, the construction of transport facilities and onshore treatment plant. Start-up is expected in the second half of 2015 with a peak production of 12 kboe/d net to Eni. Production will also feed the CEC power station. Exploration Exploration activities yielded positive results in the Marine XII offshore block with: (i) the Nené Marine 3 appraisal well confirming the oil and gas mineral potential of the area; and (ii) the significant Minsala Marine oil discovery with resources in place of approximately 1 billion boe. Exploration activities used the application of the e-dva™ proprietary technology for processing seismic imaging that allowed an optimal positioning of exploration wells. Mozambique |
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Eni Fact Book Exploration & Production
exploration campaign. To
date, resource base reached 88 Tcf located in the
different sections of the area. During the year, exploration activities yielded positive results with the appraisal gas wells Agulha 2 and Coral 4 DIR, confirming the extension of their respective discoveries. The exploration activity was underpinned by the utilization of the e-dva™ proprietary technology of processing seismic imaging. The Company is planning to develop as first target the Coral discovery and a portion of the Mamba straddling resources. As part of the Mamba plan, based on the enactment of a law decree which defines the fiscal and contractual regime applicable to onshore liquefaction projects, Eni expects to obtain the necessary authorizations to develop and produce up to 12 Tcf from the straddling reservoir via an independent industrial plan which needs to be coordinated with the operator of Area 1. An Unitization Agreement for the straddling resources has to be agreed among concessionaries of the straddling reservoirs and submitted to the Mozambique Government within six months dating back to the enactment of the special law on onshore projects which occurred in December 2014. The Coral project scheme comprises construction of a floating unit for the treatment, liquefaction and storage of natural gas (Floating LNG-FLNG) fed by subsea wells. The development plan was formally submitted to the local Authorities at the end of 2014. The FID is expected in the second half of 2015. The award of the relevant EPCIC contracts for the construction, installation and commissioning of the floating unit is expected by the end of 2015. Production start-up is expected for the end of 2019. The development plan of the first stage of the Mamba project contemplates construction and commissioning of two onshore LNG trains and the drilling of 16 subsea wells, with start-up in 2022. The scheduled activities comprise: (i) the submission of the Declaration of Commerciality to the Government by the third quarter of 2015; (ii) the filing of the development plan by the end of 2015; and (iii) the finalization of the commercial agreements and the project financing by the first quarter of 2016. The FID is expected in 2016-2017. In October 2014, Eni signed with the South Korean Company KOGAS a cooperation agreement for jointly development opportunities in the upstream and LNG areas, in particular in the Area 4 in Mozambique. Leveraging on Enis cooperation model, a medium-long term program was defined to support local communities also involving all local stakeholders as part of the development activity of the gas discoveries in the Country. The guideline of the program includes projects to develop the socio-economic conditions of local communities and respect for biodiversity. In particular, during 2014 certain projects were completed in the Pemba area in order to: (i) support the access to education, with the construction of a primary school; (ii) develop training activities in collaboration with National Institute for Employment and Vocational Training (INEFP) also supplying educational materials; and (iii) enhance the national health service, also with the restructuring of some hospital departments and specific course dedicated to health staff. In the Pemba area ongoing activities also concerned: (i) access to water with construction of a supply system for approximately 4,000 people; and (ii) studies of access to energy for rural communities also with renewable energy supplies. In addition, the construction of a gas fired power plant for domestic consumption is being planned with the support of the Mozambican Government. Eni performed with the support of the Danish Institute for Human Rights and in line with the UN Guiding Principles on Business and Human Rights a preliminary assessment of the potential impacts of the natural gas development projects on human rights in the Country. |
Nigeria Eni has been present in Nigeria since 1962. In 2014, Enis oil and gas production amounted to 135 kboe/d over a developed and undeveloped acreage of 36,123 square kilometers (7,638 square kilometers net to Eni) located mainly in the onshore and offshore of the Niger Delta. In the development/production phase Eni operates onshore Oil Mining Leases (OML) 60, 61, 62 and 63 (Enis interest 20%) and offshore OML 125 (Enis interest 85%) and OPL 245 (Enis interest 50%), holding interests in OML 118 (Enis interest 12.5%) and in OML 116 and 119 Service Contracts. As partners of SPDC JV, the largest joint venture in the Country, Eni also holds a 5% interest in 21 onshore blocks and in 5 conventional offshore blocks. In the exploration phase Eni operates offshore OML 134 (Enis interest 85%) and OPL 2009 (Enis interest 49%); onshore OPL 282 (Enis interest 90%) and OPL 135 (Enis interest 48%). Eni also holds a 12.5% interest in OML 135. The project of the Kwale-Akri pipeline in the Niger Delta is almost completed. The e-vpms™ (eni-vibroacoustic pipeline monitoring system) proprietary technology installed with the aim of identify leaks in real time and significantly reducing bunkering. During the year, supporting programs for the local community progressed with main activities in the construction of public infrastructure, improving the quality of education services, enhancing of basic health services, expanding the access to energy for local area, as well as training programs to promote the economic development, in particular in the agricultural sector. Eni launched a website to report the sustainability activity performed in the Country. In particular, information and data related to oil spills, gas flared emissions and a summary on the environmental impact studies are available. In 2014, the Petroleum Technology Association of Nigeria recognized two Enis subsidiaries as the best organizations to promote local content in the oil and gas sector in Nigeria (Local Content Operator). This award reaffirmed the Enis commitment in the implementation of effective initiatives to boost local economic activities also to achieve the high standard requirements in the oil and gas sector. Exploration and production activities in Nigeria are regulated mainly by production sharing agreements and concession contracts, as well as service contracts, in two blocks, where Eni acts as contractor for state-owned company. Blocks OMLs 60,
61, 62 and 63 |
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Eni Fact Book Exploration & Production
Block OML 118 Production The Bonga oil field produced approximately 15 kbbl/d of oil net to Eni in 2014. Production is supported by an FPSO unit with a 225 kbbl/d treatment capacity and a 2 mmbbl storage capacity. Associated gas is carried to a collection platform on the EA field and, from there, is delivered to the Bonny liquefaction plant. In the year production start-up was achieved at the Bonga NW field with the drilling and completion of 4 production and 2 injection wells. Block OML 119 Block OML 116 Block OML 125 |
SPDC Joint
Venture (NASE) In 2014, production from the SPDC JV accounted for approximately 27% of Enis production in Nigeria (36 kboe/d). Development activities progressed at the OML 28 block: (i) the drilling campaign progressed within the integrated oil and natural gas project in the Gbaran-Ubie area. The development plan provides for the supply of natural gas to the Bonny liquefaction plant by means of the construction of a Central Processing Facility (CPF) with a treatment capacity of approximately 1 bcf/d of gas and 120 kbbl/d of liquids; and (ii) the development plan of the Forkados-Yokri field includes the drilling of 24 producing wells, the upgrading of existing flowstations and the construction of transport facilities. Start-up is expected in 2015. The LNG business in
Nigeria |
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Eni Fact Book Exploration & Production
exported to European, Asian
and US markets by the Bonny Gas Transport fleet, wholly
owned by Nigeria LNG Co. n Kazakhstan Eni has been present in Kazakhstan since 1992. Eni
co-operates the Karachaganak producing field and is a
partner of the consortium of the North Caspian Sea PSA
(NCSPSA) to develop the Kashagan field. Kashagan |
development plan (the
Experimental Program). The findings of the assessment
confirmed the necessity to fully replace the damaged
pipelines. The Consortium recently finalized the
contracts for the replacement of both oil and gas lines.
The Consortium expects to complete the installation works
in the second half of 2016 with production re-start by
the end of 2016. The planned production rate will be
achieved during 2017. The Phase 1 is targeting an initial production capacity of 180 kbbl/d; when a second offshore treatment train comes online and compression facilities for gas reinjection are operational production capacity will ramp up to 370 kbbl/d. The partners are planning to further increase available production capacity up to 450 kbbl/d by installing additional gas compression capacity for reinjection in the reservoir. The partners submitted the scheme of this additional phase to the relevant Kazakh Authorities. In December 2014, the Consortium and the Kazakh Government signed an agreement which settled a number of pending issues relating to financial, environmental and operational matters. In 2014, the Consortium agreed a new setup of the operating model to execute the development of the project, targeting to streamline decision-making process, to increase efficiency in operations and to reduce costs. This new operating model provides that a company, participated by the seven partners of the Consortium, acts as the sole operator of all exploration, development and production activities at the Kashagan field. As part of this process, in 2014 the shareholding in AKCO NV (Enis interest 100%) was transferred to NCOC BV. The activities needed to set up the new operating model will be completed by the first half of 2015. An innovative environmental monitoring system was implemented in 2014. The project designed by Eni provides for the application of a mobile underwater vehicle (AUV) able to realize an environmental monitoring and asset integrity at the production facility. During the year the integrated program for the management of biodiversity in the Ural Delta (Ural River Park Project - URPP) was completed. The program was launched by Eni under the sponsorship of the Environment and Water Resources Kazakh Authority and aimed to protect the environment and ecosystems in the Caspian area. In June 2014 the project received an official UNESCO designation to be included in the Man and Biosphere Program. Within the agreements reached with the local Authorities, Eni continues its training program for Kazakh resources in the oil&gas sector. Karachaganak |
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Eni Fact Book Exploration & Production
Development The
expansion project is currently being assessed by the
Consortium by means of the installation, in stages, of
gas treatment plants and re-injection facilities to
support liquids production plateau and increase gas
marketable volumes. Phase-one development to increase injection and treatment capacity of natural gas are under economical and technical assessment. Further development projects to support liquids production plateau are under study. Eni continues its involvement to support local communities by means of the construction of schools and educational facilities, as well as water supply plant and road infrastructures for the villages located in the nearby area of Karachaganak, in particular in the western area. n Rest of Asia Indonesia Iraq |
plant for a capacity of 300
kbbl/d, the revamping of existing treatment facilities
and the drilling of production and water injection wells. In March 2014, the national oil company South Oil Co sanctioned the Enhanced Redevelopment Plan to achieve a production plateau of 850 kbbl/d. The main contracts to build new facilities were awarded in the first half of 2014. Activities to support local farms and communities progressed during the year. Pakistan Turkmenistan |
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Eni Fact Book Exploration & Production
n Americas Ecuador Trinidad & Tobago United States Gulf of Mexico |
In 2014, Eni was awarded the operatorship of
exploration licenses MC246 and MC290 with a 100%
interest. Texas |
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Eni Fact Book Exploration & Production
Exploration
Exploration activities yielded positive results with the
Stallings 1H and Mitchell 1H exploratory wells, under the
agreement with Quicksilver Resources signed at the end of
2013 providing for joint evaluation, exploration and
development of unconventional oil reservoirs (shale oil)
in the southern part of the Delaware Basin in West Texas.
The wells were already connected to existing production
facilities with an initial flow of 1,500 bbl/d. Eni was awarded in the Leon Valley (Western Texas) with a 50% interest for exploring and developing an area with unconventional oil reservoirs. Alaska Venezuela |
long-term production plateau
of approximately 1,200 mmcf/d from 2020. Exploration Eni is also participating with a 19.5% interest in Petrolera Güiria for oil exploration and with a 40% interest in Punta Pescador and Gulf of Paria Ovest for gas exploration, both located offshore in the Eastern Venezuela. n Australia and Oceania Australia Block JPDA 03-13 Block JPDA 06-105 Block WA-33-L |
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Eni Fact Book Exploration & Production
Estimated net proved hydrocarbons reserves by geographic area | (mmboe) |
(at December 31) | Italy (a) | Rest of Europe | North Africa | Sub-Saharan Africa | Kazakhstan | Rest of Asia | Americas | Australia and Oceania | Total | |||||||||
2010 | ||||||||||||||||||
Estimated net proved hydrocarbons reserves | 724 | 601 | 2,119 | 1,161 | 1,126 | 612 | 373 | 127 | 6,843 | |||||||||
Consolidated subsidiaries | 724 | 601 | 2,096 | 1,133 | 1,126 | 295 | 230 | 127 | 6,332 | |||||||||
Equity-accounted entities | 23 | 28 | 317 | 143 | 511 | |||||||||||||
Developed | 554 | 405 | 1,237 | 817 | 543 | 182 | 167 | 117 | 4,022 | |||||||||
Consolidated subsidiaries | 554 | 405 | 1,215 | 812 | 543 | 139 | 141 | 117 | 3,926 | |||||||||
Equity-accounted entities | 22 | 5 | 43 | 26 | 96 | |||||||||||||
Undeveloped | 170 | 196 | 882 | 344 | 583 | 430 | 206 | 10 | 2,821 | |||||||||
Consolidated subsidiaries | 170 | 196 | 881 | 321 | 583 | 156 | 89 | 10 | 2,406 | |||||||||
Equity-accounted entities | 1 | 23 | 274 | 117 | 415 | |||||||||||||
2011 | ||||||||||||||||||
Estimated net proved hydrocarbons reserves | 707 | 630 | 2,052 | 1,104 | 950 | 886 | 624 | 133 | 7,086 | |||||||||
Consolidated subsidiaries | 707 | 630 | 2,031 | 1,021 | 950 | 230 | 238 | 133 | 5,940 | |||||||||
Equity-accounted entities | 21 | 83 | 656 | 386 | 1,146 | |||||||||||||
Developed | 540 | 374 | 1,194 | 746 | 482 | 134 | 188 | 112 | 3,770 | |||||||||
Consolidated subsidiaries | 540 | 374 | 1,175 | 742 | 482 | 129 | 162 | 112 | 3,716 | |||||||||
Equity-accounted entities | 19 | 4 | 5 | 26 | 54 | |||||||||||||
Undeveloped | 167 | 256 | 858 | 358 | 468 | 752 | 436 | 21 | 3,316 | |||||||||
Consolidated subsidiaries | 167 | 256 | 856 | 279 | 468 | 101 | 76 | 21 | 2,224 | |||||||||
Equity-accounted entities | 2 | 79 | 651 | 360 | 1,092 | |||||||||||||
2012 | ||||||||||||||||||
Estimated net proved hydrocarbons reserves | 524 | 591 | 1,935 | 1,129 | 1,041 | 852 | 966 | 128 | 7,166 | |||||||||
Consolidated subsidiaries | 524 | 591 | 1,915 | 1,048 | 1,041 | 184 | 236 | 128 | 5,667 | |||||||||
Equity-accounted entities | 20 | 81 | 668 | 730 | 1,499 | |||||||||||||
Developed | 406 | 349 | 1,100 | 716 | 458 | 190 | 190 | 107 | 3,516 | |||||||||
Consolidated subsidiaries | 406 | 349 | 1,080 | 716 | 458 | 108 | 170 | 107 | 3,394 | |||||||||
Equity-accounted entities | 20 | 82 | 20 | 122 | ||||||||||||||
Undeveloped | 118 | 242 | 835 | 413 | 583 | 662 | 776 | 21 | 3,650 | |||||||||
Consolidated subsidiaries | 118 | 242 | 835 | 332 | 583 | 76 | 66 | 21 | 2,273 | |||||||||
Equity-accounted entities | 81 | 586 | 710 | 1,377 | ||||||||||||||
2013 | ||||||||||||||||||
Estimated net proved hydrocarbons reserves | 499 | 557 | 1,802 | 1,230 | 1,035 | 270 | 966 | 176 | 6,535 | |||||||||
Consolidated subsidiaries | 499 | 557 | 1,783 | 1,155 | 1,035 | 263 | 240 | 176 | 5,708 | |||||||||
Equity-accounted entities | 19 | 75 | 7 | 726 | 827 | |||||||||||||
Developed | 408 | 343 | 1,022 | 701 | 566 | 93 | 171 | 123 | 3,427 | |||||||||
Consolidated subsidiaries | 408 | 343 | 1,003 | 701 | 566 | 90 | 153 | 123 | 3,387 | |||||||||
Equity-accounted entities | 19 | 3 | 18 | 40 | ||||||||||||||
Undeveloped | 91 | 214 | 780 | 529 | 469 | 177 | 795 | 53 | 3,108 | |||||||||
Consolidated subsidiaries | 91 | 214 | 780 | 454 | 469 | 173 | 87 | 53 | 2,321 | |||||||||
Equity-accounted entities | 75 | 4 | 708 | 787 | ||||||||||||||
2014 | ||||||||||||||||||
Estimated net proved hydrocarbons reserves | 503 | 544 | 1,756 | 1,320 | 1,069 | 290 | 960 | 160 | 6,602 | |||||||||
Consolidated subsidiaries | 503 | 544 | 1,740 | 1,239 | 1,069 | 285 | 232 | 160 | 5,772 | |||||||||
Equity-accounted entities | 16 | 81 | 5 | 728 | 830 | |||||||||||||
Developed | 401 | 335 | 919 | 725 | 589 | 115 | 214 | 135 | 3,433 | |||||||||
Consolidated subsidiaries | 401 | 335 | 904 | 702 | 589 | 112 | 188 | 135 | 3,366 | |||||||||
Equity-accounted entities | 15 | 23 | 3 | 26 | 67 | |||||||||||||
Undeveloped | 102 | 209 | 837 | 595 | 480 | 175 | 746 | 25 | 3,169 | |||||||||
Consolidated subsidiaries | 102 | 209 | 836 | 537 | 480 | 173 | 44 | 25 | 2,406 | |||||||||
Equity-accounted entities | 1 | 58 | 2 | 702 | 763 | |||||||||||||
(a) Including approximately 767 billion of cubic feet of natural gas held in storage at December 31, 2010 and 2011. |
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Eni Fact Book Exploration & Production
Estimated net proved liquids reserves by geographic area | (mmbbl) |
(at December 31) | Italy | Rest of Europe | North Africa | Sub-Saharan Africa | Kazakhstan | Rest of Asia | Americas | Australia and Oceania | Total | |||||||||
2010 | ||||||||||||||||||
Estimated net proved liquids reserves | 248 | 349 | 997 | 756 | 788 | 183 | 273 | 29 | 3,623 | |||||||||
Consolidated subsidiaries | 248 | 349 | 978 | 750 | 788 | 139 | 134 | 29 | 3,415 | |||||||||
Equity-accounted entities | 19 | 6 | 44 | 139 | 208 | |||||||||||||
Developed | 183 | 207 | 674 | 537 | 251 | 44 | 87 | 20 | 2,003 | |||||||||
Consolidated subsidiaries | 183 | 207 | 656 | 533 | 251 | 39 | 62 | 20 | 1,951 | |||||||||
Equity-accounted entities | 18 | 4 | 5 | 25 | 52 | |||||||||||||
Undeveloped | 65 | 142 | 323 | 219 | 537 | 139 | 186 | 9 | 1,620 | |||||||||
Consolidated subsidiaries | 65 | 142 | 322 | 217 | 537 | 100 | 72 | 9 | 1,464 | |||||||||
Equity-accounted entities | 1 | 2 | 39 | 114 | 156 | |||||||||||||
2011 | ||||||||||||||||||
Estimated net proved liquids reserves | 259 | 372 | 934 | 692 | 653 | 216 | 283 | 25 | 3,434 | |||||||||
Consolidated subsidiaries | 259 | 372 | 917 | 670 | 653 | 106 | 132 | 25 | 3,134 | |||||||||
Equity-accounted entities | 17 | 22 | 110 | 151 | 300 | |||||||||||||
Developed | 184 | 195 | 638 | 487 | 215 | 34 | 117 | 25 | 1,895 | |||||||||
Consolidated subsidiaries | 184 | 195 | 622 | 483 | 215 | 34 | 92 | 25 | 1,850 | |||||||||
Equity-accounted entities | 16 | 4 | 25 | 45 | ||||||||||||||
Undeveloped | 75 | 177 | 296 | 205 | 438 | 182 | 166 | 1,539 | ||||||||||
Consolidated subsidiaries | 75 | 177 | 295 | 187 | 438 | 72 | 40 | 1,284 | ||||||||||
Equity-accounted entities | 1 | 18 | 110 | 126 | 255 | |||||||||||||
2012 | ||||||||||||||||||
Estimated net proved liquids reserves | 227 | 351 | 921 | 688 | 670 | 196 | 273 | 24 | 3,350 | |||||||||
Consolidated subsidiaries | 227 | 351 | 904 | 672 | 670 | 82 | 154 | 24 | 3,084 | |||||||||
Equity-accounted entities | 17 | 16 | 114 | 119 | 266 | |||||||||||||
Developed | 165 | 180 | 601 | 456 | 203 | 49 | 128 | 24 | 1,806 | |||||||||
Consolidated subsidiaries | 165 | 180 | 584 | 456 | 203 | 41 | 109 | 24 | 1,762 | |||||||||
Equity-accounted entities | 17 | 8 | 19 | 44 | ||||||||||||||
Undeveloped | 62 | 171 | 320 | 232 | 467 | 147 | 145 | 1,544 | ||||||||||
Consolidated subsidiaries | 62 | 171 | 320 | 216 | 467 | 41 | 45 | 1,322 | ||||||||||
Equity-accounted entities | 16 | 106 | 100 | 222 | ||||||||||||||
2013 | ||||||||||||||||||
Estimated net proved liquids reserves | 220 | 330 | 846 | 738 | 679 | 129 | 263 | 22 | 3,227 | |||||||||
Consolidated subsidiaries | 220 | 330 | 830 | 723 | 679 | 128 | 147 | 22 | 3,079 | |||||||||
Equity-accounted entities | 16 | 15 | 1 | 116 | 148 | |||||||||||||
Developed | 177 | 179 | 577 | 465 | 295 | 38 | 115 | 20 | 1,866 | |||||||||
Consolidated subsidiaries | 177 | 179 | 561 | 465 | 295 | 38 | 96 | 20 | 1,831 | |||||||||
Equity-accounted entities | 16 | 19 | 35 | |||||||||||||||
Undeveloped | 43 | 151 | 269 | 273 | 384 | 91 | 148 | 2 | 1,361 | |||||||||
Consolidated subsidiaries | 43 | 151 | 269 | 258 | 384 | 90 | 51 | 2 | 1,248 | |||||||||
Equity-accounted entities | 15 | 1 | 97 | 113 | ||||||||||||||
2014 | ||||||||||||||||||
Estimated net proved liquids reserves | 243 | 331 | 790 | 756 | 697 | 132 | 264 | 13 | 3,226 | |||||||||
Consolidated subsidiaries | 243 | 331 | 776 | 739 | 697 | 131 | 147 | 13 | 3,077 | |||||||||
Equity-accounted entities | 14 | 17 | 1 | 117 | 149 | |||||||||||||
Developed | 184 | 174 | 534 | 477 | 306 | 64 | 142 | 12 | 1,893 | |||||||||
Consolidated subsidiaries | 184 | 174 | 521 | 470 | 306 | 64 | 116 | 12 | 1,847 | |||||||||
Equity-accounted entities | 13 | 7 | 26 | 46 | ||||||||||||||
Undeveloped | 59 | 157 | 256 | 279 | 391 | 68 | 122 | 1 | 1,333 | |||||||||
Consolidated subsidiaries | 59 | 157 | 255 | 269 | 391 | 67 | 31 | 1 | 1,230 | |||||||||
Equity-accounted entities | 1 | 10 | 1 | 91 | 103 | |||||||||||||
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Eni Fact Book Exploration & Production
Estimated net proved natural gas reserves by geographic area | (bcf) |
(at December 31) | Italy (a) | Rest of Europe | North Africa | Sub-Saharan Africa | Kazakhstan | Rest of Asia | Americas | Australia and Oceania | Total | |||||||||
2010 | ||||||||||||||||||
Estimated net proved natural gas reserves | 2,644 | 1,401 | 6,231 | 2,245 | 1,874 | 2,391 | 552 | 544 | 17,882 | |||||||||
Consolidated subsidiaries | 2,644 | 1,401 | 6,207 | 2,127 | 1,874 | 871 | 530 | 544 | 16,198 | |||||||||
Equity-accounted entities | 24 | 118 | 1,520 | 22 | 1,684 | |||||||||||||
Developed | 2,061 | 1,103 | 3,122 | 1,554 | 1,621 | 774 | 437 | 539 | 11,211 | |||||||||
Consolidated subsidiaries | 2,061 | 1,103 | 3,100 | 1,550 | 1,621 | 560 | 431 | 539 | 10,965 | |||||||||
Equity-accounted entities | 22 | 4 | 214 | 6 | 246 | |||||||||||||
Undeveloped | 583 | 298 | 3,109 | 691 | 253 | 1,617 | 115 | 5 | 6,671 | |||||||||
Consolidated subsidiaries | 583 | 298 | 3,107 | 577 | 253 | 311 | 99 | 5 | 5,233 | |||||||||
Equity-accounted entities | 2 | 114 | 1,306 | 16 | 1,438 | |||||||||||||
2011 | ||||||||||||||||||
Estimated net proved natural gas reserves | 2,491 | 1,427 | 6,210 | 2,287 | 1,648 | 3,718 | 1,897 | 604 | 20,282 | |||||||||
Consolidated subsidiaries | 2,491 | 1,425 | 6,190 | 1,949 | 1,648 | 685 | 590 | 604 | 15,582 | |||||||||
Equity-accounted entities | 2 | 20 | 338 | 3,033 | 1,307 | 4,700 | ||||||||||||
Developed | 1,977 | 995 | 3,087 | 1,441 | 1,480 | 552 | 393 | 491 | 10,416 | |||||||||
Consolidated subsidiaries | 1,977 | 995 | 3,070 | 1,437 | 1,480 | 528 | 385 | 491 | 10,363 | |||||||||
Equity-accounted entities | 17 | 4 | 24 | 8 | 53 | |||||||||||||
Undeveloped | 514 | 432 | 3,123 | 846 | 168 | 3,166 | 1,504 | 113 | 9,866 | |||||||||
Consolidated subsidiaries | 514 | 430 | 3,120 | 512 | 168 | 157 | 205 | 113 | 5,219 | |||||||||
Equity-accounted entities | 2 | 3 | 334 | 3,009 | 1,299 | 4,647 | ||||||||||||
2012 | ||||||||||||||||||
Estimated net proved natural gas reserves | 1,633 | 1,317 | 5,574 | 2,414 | 2,038 | 3,605 | 3,804 | 572 | 20,957 | |||||||||
Consolidated subsidiaries | 1,633 | 1,317 | 5,558 | 2,061 | 2,038 | 562 | 449 | 572 | 14,190 | |||||||||
Equity-accounted entities | 16 | 353 | 3,043 | 3,355 | 6,767 | |||||||||||||
Developed | 1,325 | 925 | 2,736 | 1,429 | 1,401 | 774 | 340 | 459 | 9,389 | |||||||||
Consolidated subsidiaries | 1,325 | 925 | 2,720 | 1,429 | 1,401 | 372 | 334 | 459 | 8,965 | |||||||||
Equity-accounted entities | 16 | 402 | 6 | 424 | ||||||||||||||
Undeveloped | 308 | 392 | 2,838 | 985 | 637 | 2,831 | 3,464 | 113 | 11,568 | |||||||||
Consolidated subsidiaries | 308 | 392 | 2,838 | 632 | 637 | 190 | 115 | 113 | 5,225 | |||||||||
Equity-accounted entities | 353 | 2,641 | 3,349 | 6,343 | ||||||||||||||
2013 | ||||||||||||||||||
Estimated net proved natural gas reserves | 1,532 | 1,247 | 5,246 | 2,704 | 1,957 | 772 | 3,862 | 848 | 18,168 | |||||||||
Consolidated subsidiaries | 1,532 | 1,247 | 5,231 | 2,374 | 1,957 | 744 | 509 | 848 | 14,442 | |||||||||
Equity-accounted entities | 15 | 330 | 28 | 3,353 | 3,726 | |||||||||||||
Developed | 1,266 | 904 | 2,447 | 1,295 | 1,488 | 300 | 315 | 561 | 8,576 | |||||||||
Consolidated subsidiaries | 1,266 | 904 | 2,432 | 1,295 | 1,488 | 286 | 310 | 561 | 8,542 | |||||||||
Equity-accounted entities | 15 | 14 | 5 | 34 | ||||||||||||||
Undeveloped | 266 | 343 | 2,799 | 1,409 | 469 | 472 | 3,547 | 287 | 9,592 | |||||||||
Consolidated subsidiaries | 266 | 343 | 2,799 | 1,079 | 469 | 458 | 199 | 287 | 5,900 | |||||||||
Equity-accounted entities | 330 | 14 | 3,348 | 3,692 | ||||||||||||||
2014 | ||||||||||||||||||
Estimated net proved natural gas reserves | 1,432 | 1,171 | 5,306 | 3,095 | 2,049 | 864 | 3,821 | 807 | 18,545 | |||||||||
Consolidated subsidiaries | 1,432 | 1,171 | 5,291 | 2,744 | 2,049 | 846 | 468 | 807 | 14,808 | |||||||||
Equity-accounted entities | 15 | 351 | 18 | 3,353 | 3,737 | |||||||||||||
Developed | 1,192 | 887 | 2,125 | 1,360 | 1,553 | 271 | 399 | 675 | 8,462 | |||||||||
Consolidated subsidiaries | 1,192 | 887 | 2,110 | 1,271 | 1,553 | 261 | 393 | 675 | 8,342 | |||||||||
Equity-accounted entities | 15 | 89 | 10 | 6 | 120 | |||||||||||||
Undeveloped | 240 | 284 | 3,181 | 1,735 | 496 | 593 | 3,422 | 132 | 10,083 | |||||||||
Consolidated subsidiaries | 240 | 284 | 3,181 | 1,473 | 496 | 585 | 75 | 132 | 6,466 | |||||||||
Equity-accounted entities | 262 | 8 | 3,347 | 3,617 | ||||||||||||||
(a) Including approximately 767 billion of cubic feet of natural gas held in storage at December 31, 2010 and 2011. |
- 30 -
Eni Fact Book Exploration & Production
Production of oil and natural gas by country (a) |
(kboe/d) | 2010 |
2011 |
2012 |
2013 |
2014 |
Italy | 183 | 186 | 189 | 186 | 179 | |||||
Rest of Europe | 222 | 216 | 178 | 155 | 190 | |||||
Croatia | 8 | 5 | 5 | 8 | 7 | |||||
Norway | 123 | 131 | 126 | 106 | 112 | |||||
United Kingdom | 91 | 80 | 47 | 41 | 71 | |||||
North Africa | 602 | 438 | 586 | 556 | 567 | |||||
Algeria | 77 | 72 | 78 | 88 | 109 | |||||
Egypt | 232 | 236 | 235 | 227 | 206 | |||||
Libya | 273 | 112 | 258 | 228 | 239 | |||||
Tunisia | 20 | 18 | 15 | 13 | 13 | |||||
Sub-Saharan Africa | 400 | 370 | 345 | 332 | 325 | |||||
Angola | 118 | 102 | 87 | 87 | 84 | |||||
Congo | 110 | 108 | 104 | 120 | 106 | |||||
Nigeria | 172 | 160 | 154 | 125 | 135 | |||||
Kazakhstan | 108 | 106 | 102 | 100 | 88 | |||||
Rest of Asia | 131 | 112 | 129 | 144 | 98 | |||||
China | 7 | 8 | 9 | 8 | 4 | |||||
India | 8 | 4 | 2 | 1 | 1 | |||||
Indonesia | 19 | 18 | 18 | 16 | 16 | |||||
Iran | 21 | 6 | 3 | 4 | 1 | |||||
Iraq | 5 | 7 | 18 | 22 | 21 | |||||
Pakistan | 59 | 58 | 57 | 52 | 45 | |||||
Russia | 11 | 31 | ||||||||
Turkmenistan | 12 | 11 | 11 | 10 | 10 | |||||
Americas | 143 | 125 | 135 | 116 | 125 | |||||
Brazil | 1 | 2 | ||||||||
Ecuador | 11 | 7 | 25 | 13 | 12 | |||||
Trinidad & Tobago | 12 | 10 | 11 | 11 | 11 | |||||
United States | 109 | 98 | 88 | 82 | 92 | |||||
Venezuela | 11 | 9 | 9 | 10 | 10 | |||||
Australia and Oceania | 26 | 28 | 37 | 30 | 26 | |||||
Australia | 26 | 28 | 37 | 30 | 26 | |||||
Total outside Italy | 1,632 | 1,395 | 1,512 | 1,433 | 1,419 | |||||
1,815 | 1,581 | 1,701 | 1,619 | 1,598 | ||||||
of which equity-accounted entities | 25 | 26 | 35 | 54 | 22 | |||||
Angola | 3 | 4 | 2 | 3 | 2 | |||||
Brazil | 1 | 2 | ||||||||
Indonesia | 6 | 6 | 6 | 5 | 5 | |||||
Russia | 11 | 31 | ||||||||
Tunisia | 5 | 6 | 5 | 5 | 5 | |||||
Venezuela | 11 | 9 | 9 | 10 | 10 |
Oil and natural gas production sold |
(mmboe) | 2010 |
2011 |
2012 |
2013 |
2014 |
Oil and natural gas production | 662.3 | 577.0 | 622.6 | 591.0 | 583.1 | ||||||||||||
Change in inventories and other | (3.4 | ) | (7.4 | ) | 1.6 | (5.7 | ) | (4.2 | ) | ||||||||
Own consumption of gas | (20.9 | ) | (21.1 | ) | (25.5 | ) | (30.0 | ) | (29.4 | ) | |||||||
Oil and natural gas production sold (b) | 638.0 | 548.5 | 598.7 | 555.3 | 549.5 | ||||||||||||
Oil | (mmbbl) | 361.30 | 302.61 | 325.41 | 299.54 | 299.78 | |||||||||||
- of which to R&M segment | 206.41 | 190.65 | 185.48 | 178.83 | 184.09 | ||||||||||||
Natural gas | (bcf) | 1,536 | 1,367 | 1,501 | 1,405 | 1,371 | |||||||||||
- of which to G&P segment | 432 | 423 | 435 | 385 | 371 | ||||||||||||
(a) Includes
volumes of gas consumed in operations (442, 451, 383, 321
and 318 mmcf/d, in 2014, 2013, 2012, 2011 and 2010,
respectively). (b) Includes 6.1 mmboe of equity-accounted entities production sold in 2014 (17.1, 11.2, 7.7 and 8 mmboe in 2013, 2012, 2011 and 2010, respectively). |
- 31 -
Eni Fact Book Exploration & Production
Liquids production by country |
(kbbl/d) | 2010 |
2011 |
2012 |
2013 |
2014 |
Italy | 61 | 64 | 63 | 71 | 73 | |||||
Rest of Europe | 121 | 120 | 95 | 77 | 93 | |||||
Norway | 74 | 80 | 74 | 60 | 62 | |||||
United Kingdom | 47 | 40 | 21 | 17 | 31 | |||||
North Africa | 301 | 209 | 271 | 252 | 252 | |||||
Algeria | 74 | 69 | 71 | 73 | 83 | |||||
Egypt | 96 | 91 | 88 | 93 | 88 | |||||
Libya | 116 | 36 | 101 | 76 | 73 | |||||
Tunisia | 15 | 13 | 11 | 10 | 8 | |||||
Sub-Saharan Africa | 321 | 278 | 247 | 242 | 231 | |||||
Angola | 113 | 95 | 80 | 79 | 75 | |||||
Congo | 98 | 87 | 82 | 90 | 80 | |||||
Nigeria | 110 | 96 | 85 | 73 | 76 | |||||
Kazakhstan | 65 | 64 | 61 | 61 | 52 | |||||
Rest of Asia | 48 | 34 | 44 | 49 | 37 | |||||
China | 6 | 7 | 8 | 7 | 4 | |||||
India | 1 | |||||||||
Indonesia | 2 | 2 | 2 | 2 | 2 | |||||
Iran | 21 | 6 | 3 | 4 | 1 | |||||
Iraq | 5 | 7 | 18 | 22 | 21 | |||||
Pakistan | 1 | 1 | 1 | |||||||
Russia | 2 | 5 | ||||||||
Turkmenistan | 12 | 11 | 10 | 9 | 9 | |||||
Americas | 71 | 65 | 83 | 71 | 84 | |||||
Brazil | 1 | 2 | ||||||||
Ecuador | 11 | 7 | 25 | 13 | 12 | |||||
United States | 49 | 48 | 47 | 48 | 62 | |||||
Venezuela | 11 | 9 | 9 | 10 | 10 | |||||
Australia and Oceania | 9 | 11 | 18 | 10 | 6 | |||||
Australia | 9 | 11 | 18 | 10 | 6 | |||||
Total outside Italy | 936 | 781 | 819 | 762 | 755 | |||||
997 | 845 | 882 | 833 | 828 | ||||||
of which equity-accounted entities | 19 | 19 | 20 | 20 | 15 | |||||
Angola | 3 | 3 | 2 | |||||||
Brazil | 1 | 2 | ||||||||
Indonesia | 1 | 1 | 1 | 1 | 1 | |||||
Russia | 2 | 5 | ||||||||
Tunisia | 4 | 5 | 4 | 4 | 4 | |||||
Venezuela | 11 | 9 | 9 | 10 | 10 |
Oil and natural gas production available for sale (a) |
(kboe/d) | 2010 |
2011 |
2012 |
2013 |
2014 |
Italy | 178 | 181 | 184 | 179 | 171 | |||||
Rest of Europe | 214 | 209 | 171 | 149 | 184 | |||||
North Africa | 582 | 420 | 561 | 528 | 532 | |||||
Sub-Saharan Africa | 386 | 354 | 328 | 307 | 307 | |||||
Kazakhstan | 104 | 102 | 98 | 96 | 85 | |||||
Rest of Asia | 126 | 106 | 121 | 135 | 91 | |||||
Americas | 141 | 124 | 133 | 114 | 122 | |||||
Australia and Oceania | 26 | 27 | 35 | 29 | 25 | |||||
1,757 | 1,523 | 1,631 | 1,537 | 1,517 | ||||||
of which equity-accounted entities | 23 | 23 | 33 | 51 | 20 | |||||
North Africa | 5 | 5 | 5 | 5 | 4 | |||||
Sub-Saharan Africa | 3 | 3 | 2 | 2 | 2 | |||||
Rest of Asia | 5 | 4 | 15 | 34 | 4 | |||||
Americas | 10 | 11 | 11 | 10 | 10 |
(a) Do not include natural gas consumed in operations. |
- 32 - |
Eni Fact Book Exploration & Production
Natural gas production by country (a) |
(mmcf/d) | 2010 |
2011 |
2012 |
2013 |
2014 |
Italy | 673.2 | 674.3 | 695.1 | 630.2 | 583.8 | |||||
Rest of Europe | 559.2 | 537.9 | 458.9 | 429.6 | 535.2 | |||||
Croatia | 45.3 | 29.9 | 25.4 | 43.0 | 38.2 | |||||
Norway | 271.6 | 284.0 | 289.6 | 250.5 | 274.2 | |||||
Ukraine | 0.5 | |||||||||
United Kingdom | 242.3 | 224.0 | 143.4 | 136.1 | 222.8 | |||||
North Africa | 1,673.2 | 1,271.5 | 1,733.5 | 1,674.2 | 1,724.2 | |||||
Algeria | 20.2 | 19.0 | 40.1 | 81.6 | 141.3 | |||||
Egypt | 755.1 | 800.7 | 805.9 | 734.6 | 649.8 | |||||
Libya | 871.1 | 423.2 | 863.5 | 836.7 | 911.2 | |||||
Tunisia | 26.8 | 28.6 | 24.0 | 21.3 | 21.9 | |||||
Sub-Saharan Africa | 441.5 | 508.0 | 538.7 | 495.9 | 517.8 | |||||
Angola | 31.9 | 34.7 | 39.2 | 46.9 | 48.6 | |||||
Congo | 67.9 | 119.1 | 120.5 | 161.8 | 145.1 | |||||
Nigeria | 341.7 | 354.2 | 379.0 | 287.2 | 324.1 | |||||
Kazakhstan | 237.0 | 231.0 | 221.7 | 213.5 | 200.7 | |||||
Rest of Asia | 463.9 | 430.1 | 468.5 | 520.5 | 333.6 | |||||
China | 6.7 | 5.0 | 4.4 | 3.4 | ||||||
India | 36.6 | 19.6 | 10.5 | 7.2 | 3.7 | |||||
Indonesia | 94.4 | 84.3 | 84.9 | 79.2 | 75.8 | |||||
Pakistan | 326.2 | 321.2 | 310.4 | 283.1 | 248.2 | |||||
Russia | 52.4 | 141.6 | ||||||||
Turkmenistan | 5.9 | 6.0 | 5.9 | |||||||
Americas | 396.0 | 334.0 | 283.5 | 245.3 | 218.6 | |||||
Trinidad & Tobago | 63.6 | 56.7 | 58.5 | 58.6 | 60.3 | |||||
United States | 332.4 | 277.3 | 225.0 | 185.9 | 157.5 | |||||
Venezuela | 0.8 | 0.8 | ||||||||
Australia and Oceania | 95.7 | 97.8 | 100.8 | 110.4 | 110.5 | |||||
Australia | 95.7 | 97.8 | 100.8 | 110.4 | 110.5 | |||||
Total outside Italy | 3,866.5 | 3,410.3 | 3,805.6 | 3,689.4 | 3,640.6 | |||||
4,539.7 | 4,084.6 | 4,500.7 | 4,319.6 | 4,224.4 | ||||||
of which equity-accounted entities | 35.6 | 34.0 | 88.6 | 186.3 | 39.6 | |||||
Angola | 0.8 | 1.9 | 4.4 | 14.2 | 10.3 | |||||
Indonesia | 28.9 | 25.7 | 26.0 | 24.2 | 23.2 | |||||
Russia | 52.4 | 141.6 | ||||||||
Tunisia | 5.9 | 6.4 | 5.3 | 5.5 | 5.3 | |||||
Ukraine | 0.5 | |||||||||
Venezuela | 0.8 | 0.8 |
Natural gas production available for sale (b) |
(mmcf/d) | 2010 |
2011 |
2012 |
2013 |
2014 |
Italy | 648 | 648 | 667 | 593 | 541 | |||||
Rest of Europe | 517 | 498 | 421 | 395 | 498 | |||||
North Africa | 1,559 | 1,169 | 1,592 | 1,514 | 1,536 | |||||
Sub-Saharan Africa | 365 | 422 | 444 | 356 | 418 | |||||
Kazakhstan | 221 | 212 | 202 | 195 | 181 | |||||
Rest of Asia | 436 | 398 | 423 | 476 | 297 | |||||
Americas | 385 | 323 | 273 | 234 | 205 | |||||
Australia and Oceania | 91 | 93 | 96 | 105 | 106 | |||||
4,222 | 3,763 | 4,118 | 3,868 | 3,782 | ||||||
of which equity-accounted entities | 27 | 24 | 71 | 165 | 28 | |||||
North Africa | 3 | 4 | 3 | 4 | 3 | |||||
Sub-Saharan Africa | 7 | 7 | ||||||||
Rest of Asia | 24 | 20 | 68 | 154 | 18 |
(a) Includes
volumes of gas consumed in operations (442, 451, 383, 321
and 318 mmcf/d, in 2014, 2013, 2012, 2011 and 2010,
respectively). (b) Do not include natural gas consumed in operations. |
- 33 - |
Eni Fact Book Exploration & Production
Average realizations | 2010 |
2011 |
2012 |
2013 |
2014 |
CONS | JV | CONS | JV | CONS | JV | CONS | JV | CONS | JV | |||||||||||
Liquids | ||||||||||||||||||||
($/bbl) |
Italy | 72.19 | 101.20 | 100.52 | 98.50 | 87.80 | |||||||||||||||
Rest of Europe | 67.26 | 97.56 | 97.18 | 100.67 | 93.11 | 98.97 | 88.80 | |||||||||||||
North Africa | 70.96 | 16.09 | 97.63 | 17.98 | 103.63 | 17.93 | 100.42 | 17.96 | 88.99 | 17.94 | ||||||||||
Sub-Saharan Africa | 78.23 | 77.78 | 110.09 | 108.92 | 108.34 | 112.28 | 105.13 | 93.45 | ||||||||||||
Kazakhstan | 66.74 | 98.68 | 102.25 | 99.37 | 91.86 | |||||||||||||||
Rest of Asia | 75.20 | 57.05 | 101.09 | 74.98 | 103.44 | 40.36 | 99.69 | 33.87 | 77.99 | 65.90 | ||||||||||
Americas | 72.84 | 71.70 | 101.15 | 93.03 | 85.94 | 93.45 | 85.27 | 93.32 | 79.13 | 81.48 | ||||||||||
Australia and Oceania | 73.00 | 98.05 | 102.06 | 98.72 | 91.61 | |||||||||||||||
72.95 | 58.86 | 102.47 | 84.78 | 103.06 | 77.94 | 100.20 | 64.92 | 88.90 | 70.56 | |||||||||||
Natural gas | ||||||||||||||||||||
($/kcf) | ||||||||||||||||||||
Italy | 8.71 | 11.56 | 10.68 | 11.65 | 8.74 | |||||||||||||||
Rest of Europe | 7.40 | 9.72 | 10.65 | 10.13 | 11.64 | 10.62 | 8.49 | |||||||||||||
North Africa | 6.87 | 5.95 | 5.39 | 8.13 | 4.91 | 7.96 | 6.29 | 8.08 | 6.08 | |||||||||||
Sub-Saharan Africa | 1.87 | 1.97 | 2.16 | 2.16 | 2.12 | |||||||||||||||
Kazakhstan | 0.49 | 0.57 | 0.67 | 0.64 | 0.62 | |||||||||||||||
Rest of Asia | 4.35 | 9.87 | 5.27 | 15.68 | 5.94 | 6.17 | 5.83 | 3.49 | 6.18 | 15.64 | ||||||||||
Americas | 4.70 | 4.02 | 2.90 | 3.37 | 3.96 | |||||||||||||||
Australia and Oceania | 7.40 | 7.38 | 7.73 | 7.80 | 7.46 | |||||||||||||||
6.01 | 8.73 | 6.44 | 13.89 | 7.14 | 6.16 | 7.41 | 4.00 | 6.83 | 14.13 | |||||||||||
Hydrocarbons | ||||||||||||||||||||
($/boe) | ||||||||||||||||||||
Italy | 56.60 | 77.26 | 73.24 | 77.56 | 64.80 | |||||||||||||||
Rest of Europe | 56.00 | 79.03 | 66.14 | 80.79 | 69.05 | 79.14 | 67.87 | |||||||||||||
North Africa | 55.06 | 13.53 | 64.85 | 20.87 | 73.06 | 19.45 | 70.51 | 21.47 | 65.36 | 21.43 | ||||||||||
Sub-Saharan Africa | 66.35 | 77.78 | 88.02 | 108.92 | 84.93 | 112.28 | 85.08 | 73.18 | ||||||||||||
Kazakhstan | 42.24 | 62.87 | 64.92 | 62.02 | 57.20 | |||||||||||||||
Rest of Asia | 42.45 | 55.04 | 51.51 | 85.80 | 57.98 | 34.78 | 62.59 | 21.46 | 52.75 | 83.12 | ||||||||||
Americas | 47.84 | 71.70 | 60.28 | 93.03 | 54.61 | 93.45 | 57.89 | 93.32 | 59.94 | 81.48 | ||||||||||
Australia and Oceania | 52.51 | 61.00 | 73.82 | 61.79 | 52.46 | |||||||||||||||
55.59 | 56.10 | 72.20 | 83.15 | 73.65 | 59.25 | 72.97 | 37.57 | 65.36 | 72.19 | |||||||||||
Enis Group | 2010 | 2011 | 2012 | 2013 | 2014 | |||||||||||||||
Liquids ($/bbl) | 72.76 | 102.11 | 102.58 | 99.44 | 88.71 | |||||||||||||||
Natural gas ($/kcf) | 6.02 | 6.48 | 7.12 | 7.26 | 6.87 | |||||||||||||||
Hydrocarbons ($/boe) | 55.60 | 72.26 | 73.39 | 71.87 | 65.49 | |||||||||||||||
Net developed and undeveloped acreage |
(square kilometers) | 2010 |
2011 |
2012 |
2013 |
2014 |
Europe | 29,079 | 26,023 | 27,423 | 37,018 | 44,842 | |||||
Italy | 19,097 | 16,872 | 17,556 | 17,282 | 17,297 | |||||
Rest of Europe | 9,982 | 9,151 | 9,867 | 19,736 | 27,545 | |||||
Africa | 152,671 | 137,220 | 142,796 | 137,096 | 159,341 | |||||
North Africa | 44,277 | 30,532 | 21,390 | 20,412 | 21,693 | |||||
Sub-Saharan Africa | 108,394 | 106,688 | 121,406 | 116,684 | 137,648 | |||||
Asia | 112,745 | 55,284 | 58,042 | 79,314 | 109,237 | |||||
Kazakhstan | 880 | 880 | 869 | 869 | 869 | |||||
Rest of Asia | 111,865 | 54,404 | 57,173 | 78,445 | 108,368 | |||||
Americas | 11,187 | 10,209 | 9,075 | 9,206 | 7,943 | |||||
Australia and Oceania | 15,279 | 25,685 | 13,834 | 13,622 | 13,376 | |||||
Total | 320,961 | 254,421 | 251,170 | 276,256 | 334,739 |
- 34 -
Eni Fact Book Exploration & Production
Principal oil and natural gas interests at December 31, 2014 |
Commencement of operations |
Number of interests |
Gross developed (a) (b) acreage |
Net developed (a) (b) acreage |
Gross undeveloped (a) acreage |
Net undeveloped (a) acreage |
Type of fields/acreage |
Number of producing fields |
Number of other fields |
||||||||||
EUROPE | 265 | 15,883 | 10,948 | 53,444 | 33,894 | 120 | 93 | |||||||||||
Italy | 1926 | 151 | 10,712 | 8,989 | 10,751 | 8,308 | Onshore/Offshore | 81 | 68 | |||||||||
Rest of Europe | 114 | 5,171 | 1,959 | 42,693 | 25,586 | 39 | 25 | |||||||||||
Croatia | 1996 | 2 | 1,975 | 987 | Offshore | 10 | 2 | |||||||||||
Cyprus | 2013 | 3 | 12,523 | 10,018 | Offshore | |||||||||||||
Greenland | 2013 | 2 | 4,890 | 1,909 | Offshore | |||||||||||||
Norway | 1965 | 56 | 2,255 | 345 | 9,149 | 3,327 | Offshore | 18 | 20 | |||||||||
Portugal | 2014 | 3 | 9,099 | 6,370 | Offshore | |||||||||||||
United Kingdom | 1964 | 35 | 941 | 627 | 343 | 117 | Offshore | 11 | 3 | |||||||||
Other countries | 13 | 6,689 | 3,845 | Offshore | ||||||||||||||
AFRICA | 282 | 66,114 | 20,032 | 263,572 | 139,309 | 268 | 138 | |||||||||||
North Africa | 117 | 32,559 | 14,144 | 15,675 | 7,549 | 101 | 60 | |||||||||||
Algeria | 1981 | 42 | 3,222 | 1,148 | 187 | 31 | Onshore | 33 | 10 | |||||||||
Egypt | 1954 | 54 | 4,926 | 1,772 | 6,800 | 3,174 | Onshore/Offshore | 43 | 23 | |||||||||
Libya | 1959 | 10 | 17,947 | 8,950 | 8,688 | 4,344 | Onshore/Offshore | 4 | 22 | |||||||||
Tunisia | 1961 | 11 | 6,464 | 2,274 | Onshore/Offshore | 21 | 5 | |||||||||||
Sub-Saharan Africa | 165 | 33,555 | 5,888 | 247,897 | 131,760 | 167 | 78 | |||||||||||
Angola | 1980 | 72 | 6,555 | 813 | 14,605 | 3,514 | Onshore/Offshore | 50 | 33 | |||||||||
Congo | 1968 | 28 | 1,714 | 921 | 2,649 | 1,962 | Onshore/Offshore | 27 | 3 | |||||||||
Gabon | 2008 | 6 | 7,615 | 7,615 | Onshore/Offshore | |||||||||||||
Ghana | 2009 | 3 | 4,676 | 1,664 | Offshore | 2 | ||||||||||||
Kenya | 2012 | 7 | 61,363 | 40,426 | Offshore | |||||||||||||
Liberia | 2012 | 3 | 7,365 | 1,841 | Offshore | |||||||||||||
Mozambique | 2007 | 1 | 10,207 | 5,103 | Offshore | 6 | ||||||||||||
Nigeria | 1962 | 40 | 25,286 | 4,154 | 10,837 | 3,484 | Onshore/Offshore | 90 | 34 | |||||||||
South Africa | 2014 | 1 | 82,117 | 32,847 | Offshore | |||||||||||||
Other countries | 4 | 46,463 | 33,304 | Onshore | ||||||||||||||
ASIA | 71 | 17,556 | 5,809 | 199,150 | 103,428 | 29 | 24 | |||||||||||
Kazakhstan | 1992 | 6 | 2,391 | 442 | 2,542 | 427 | Onshore/Offshore | 1 | 5 | |||||||||
Rest of Asia | 65 | 15,165 | 5,367 | 196,608 | 103,001 | 28 | 19 | |||||||||||
China | 1984 | 8 | 77 | 19 | 7,056 | 7,056 | Offshore | 5 | ||||||||||
India | 2005 | 11 | 206 | 109 | 16,546 | 6,058 | Onshore/Offshore | 4 | 3 | |||||||||
Indonesia | 2001 | 14 | 3,218 | 1,217 | 31,608 | 25,031 | Onshore/Offshore | 7 | 15 | |||||||||
Iraq | 2009 | 1 | 1,074 | 446 | Onshore | 1 | ||||||||||||
Myanmar | 2014 | 2 | 7,850 | 7,065 | Onshore | |||||||||||||
Pakistan | 2000 | 17 | 10,390 | 3,396 | 15,249 | 6,071 | Onshore/Offshore | 9 | 1 | |||||||||
Russia | 2007 | 3 | 62,592 | 20,862 | Offshore | |||||||||||||
Timor Leste | 2006 | 1 | 1,538 | 1,230 | Offshore | |||||||||||||
Turkmenistan | 2008 | 1 | 200 | 180 | Onshore | 2 | ||||||||||||
Vietnam | 2013 | 6 | 39,569 | 26,384 | Offshore | |||||||||||||
Other countries | 1 | 14,600 | 3,244 | Offshore | ||||||||||||||
AMERICAS | 306 | 5,064 | 3,273 | 11,746 | 4,670 | 71 | 13 | |||||||||||
Ecuador | 1988 | 1 | 1,985 | 1,985 | Onshore | 1 | 2 | |||||||||||
Trinidad & Tobago | 1970 | 1 | 382 | 66 | Offshore | 7 | ||||||||||||
United States | 1968 | 290 | 1,895 | 954 | 4,197 | 2,546 | Onshore/Offshore | 61 | 7 | |||||||||
Venezuela | 1998 | 6 | 802 | 268 | 2,002 | 798 | Onshore/Offshore | 2 | 3 | |||||||||
Other countries | 8 | 5,547 | 1,326 | Offshore | 1 | |||||||||||||
AUSTRALIA AND OCEANIA | 14 | 1,140 | 709 | 21,679 | 12,667 | 3 | 2 | |||||||||||
Australia | 2001 | 14 | 1,140 | 709 | 21,679 | 12,667 | Offshore | 3 | 2 | |||||||||
Total | 938 | 105,757 | 40,771 | 549,591 | 293,968 | 491 | 270 | |||||||||||
(a) Square kilometers. (b) Developed acreage refers to those leases in which at least a portion of the area is in production or encompasses proved developed reserves. |
- 35 -
Eni Fact Book Exploration & Production
Capital expenditure |
(euro million) | 2010 |
2011 |
2012 |
2013 |
2014 |
Acquisition of proved and unproved properties | 754 | 43 | 109 | |||||||
North Africa | 57 | 14 | 109 | |||||||
Sub-Saharan Africa | 697 | 27 | ||||||||
Americas | 2 | |||||||||
Exploration | 1,012 | 1,210 | 1,850 | 1,669 | 1,398 | |||||
Italy | 34 | 38 | 32 | 32 | 29 | |||||
Rest of Europe | 114 | 100 | 151 | 357 | 188 | |||||
North Africa | 84 | 128 | 153 | 95 | 227 | |||||
Sub-Saharan Africa | 406 | 482 | 1,142 | 757 | 635 | |||||
Kazakhstan | 6 | 6 | 3 | 1 | ||||||
Rest of Asia | 223 | 156 | 193 | 233 | 160 | |||||
Americas | 119 | 60 | 80 | 110 | 139 | |||||
Australia and Oceania | 26 | 240 | 96 | 84 | 20 | |||||
Development | 8,578 | 7,357 | 8,304 | 8,580 | 9,021 | |||||
Italy | 630 | 720 | 744 | 743 | 880 | |||||
Rest of Europe | 863 | 1,596 | 2,008 | 1,768 | 1,574 | |||||
North Africa | 2,584 | 1,380 | 1,299 | 808 | 832 | |||||
Sub-Saharan Africa | 1,818 | 1,521 | 1,931 | 2,675 | 3,085 | |||||
Kazakhstan | 1,030 | 897 | 719 | 658 | 521 | |||||
Rest of Asia | 311 | 361 | 641 | 749 | 1,105 | |||||
Americas | 1,187 | 831 | 953 | 1,127 | 921 | |||||
Australia and Oceania | 155 | 51 | 9 | 52 | 103 | |||||
Other expenditure | 100 | 114 | 110 | 117 | 105 | |||||
9,690 | 9,435 | 10,307 | 10,475 | 10,524 | ||||||
Reserves life index |
(years) | 2010 |
2011 |
2012 |
2013 |
2014 |
Italy | 10.9 | 10.4 | 7.6 | 7.3 | 7.7 | |||||
Rest of Europe | 7.4 | 8.0 | 9.0 | 9.8 | 7.8 | |||||
North Africa | 9.6 | 12.8 | 9.0 | 8.9 | 8.5 | |||||
Sub-Saharan Africa | 7.9 | 8.2 | 8.9 | 10.2 | 11.1 | |||||
Kazakhstan | 28.7 | 24.5 | 28.1 | 28.8 | 33.4 | |||||
Rest of Asia | 12.8 | 21.7 | 18.1 | 5.1 | 8.1 | |||||
Americas | 7.2 | 13.6 | 19.7 | 23.0 | 21.3 | |||||
Australia and Oceania | 13.1 | 12.8 | 9.8 | 16.0 | 17.8 | |||||
10.3 | 12.3 | 11.5 | 11.1 | 11.3 | ||||||
Reserves replacement ratio |
2010 |
2011 |
2012 |
2013 |
2014 |
(%) | organic | all sources | organic | all sources | organic | all sources | organic | all sources | organic | all sources | ||||||||||
Italy | 121 | 107 | 72 | 75 | 34 | 62 | 62 | 106 | 106 | ||||||||||||
Rest of Europe | 103 | 102 | 140 | 136 | 37 | 37 | 63 | 40 | 77 | 81 | |||||||||||
North Africa | 167 | 167 | 58 | 58 | 40 | 40 | 32 | 34 | 78 | 78 | |||||||||||
Sub-Saharan Africa | 91 | 90 | 63 | 58 | 138 | 117 | 183 | 183 | 182 | 176 | |||||||||||
Kazakhstan | 467 | 337 | 83 | 83 | 206 | 206 | |||||||||||||||
Rest of Asia | 211 | 212 | 768 | 771 | 12 | 12 | 232 | 156 | 156 | ||||||||||||
Americas | 274 | 273 | 646 | 647 | 855 | 786 | 102 | 102 | 87 | 87 | |||||||||||
Australia and Oceania | 6 | 5 | 155 | 163 | 51 | 51 | 536 | 536 | |||||||||||||
127 | 125 | 143 | 142 | 147 | 107 | 105 | (7 | ) | 112 | 112 | |||||||||||
- 36 -
Eni Fact Book Exploration & Production
Exploratory well activity |
Net wells completed |
Wells in progress at Dec. 31 (a) |
|||
2012 |
2013 |
2014 |
2014 |
|||||
(units) | Productive |
Dry (b) |
Productive |
Dry (b) |
Productive |
Dry (b) |
Gross |
Net |
||||||||
Italy | 1.0 | 0.6 | 4.0 | 2.8 | ||||||||||||
Rest of Europe | 1.0 | 1.0 | 3.4 | 4.3 | 12.0 | 3.3 | ||||||||||
North Africa | 6.3 | 11.3 | 4.9 | 5.4 | 3.5 | 4.3 | 13.0 | 10.3 | ||||||||
Sub-Saharan Africa | 4.5 | 5.1 | 3.2 | 6.6 | 7.3 | 7.3 | 49.0 | 16.9 | ||||||||
Kazakhstan | 0.8 | 0.4 | 6.0 | 1.1 | ||||||||||||
Rest of Asia | 0.5 | 0.6 | 4.3 | 2.7 | 1.3 | 4.3 | 12.0 | 5.0 | ||||||||
Americas | 0.1 | 0.2 | 1.2 | 2.0 | 1.4 | 4.0 | 2.5 | |||||||||
Australia and Oceania | 0.4 | 0.5 | 0.9 | 1.0 | 0.3 | |||||||||||
13.3 | 19.3 | 12.6 | 20.2 | 14.1 | 23.1 | 101.0 | 42.2 |
Development well activity |
Net wells completed |
Wells in progress at Dec. 31 (a) |
|||
2012 |
2013 |
2014 |
2014 |
|||||
(units) | Productive |
Dry (b) |
Productive |
Dry (b) |
Productive |
Dry (b) |
Gross |
Net |
||||||||
Italy | 18.0 | 1.0 | 7.4 | 1.0 | 12.5 | 5.0 | 4.6 | |||||||||
Rest of Europe | 2.9 | 0.6 | 6.3 | 9.8 | 1.0 | 36.0 | 7.9 | |||||||||
North Africa | 46.0 | 1.6 | 61.6 | 3.3 | 54.5 | 1.0 | 15.0 | 7.4 | ||||||||
Sub-Saharan Africa | 27.4 | 0.3 | 26.3 | 1.2 | 31.6 | 23.0 | 7.5 | |||||||||
Kazakhstan | 1.4 | 0.3 | 1.5 | 22.0 | 3.9 | |||||||||||
Rest of Asia | 41.2 | 0.1 | 61.7 | 4.3 | 54.2 | 1.6 | 19.0 | 8.2 | ||||||||
Americas | 23.1 | 13.8 | 22.1 | 0.7 | 20.0 | 6.5 | ||||||||||
Australia and Oceania | 0.1 | 0.4 | 2.0 | 0.5 | ||||||||||||
160.0 | 3.6 | 177.4 | 9.8 | 186.3 | 4.7 | 142.0 | 46.5 |
Productive oil and gas wells (c) |
2014 |
||
Oil wells |
Natural gas wells |
|||
(units) | Gross |
Net |
Gross |
Net |
||||
Italy | 241.0 | 195.1 | 615.0 | 532.4 | ||||
Rest of Europe | 354.0 | 60.6 | 188.0 | 102.9 | ||||
North Africa | 1,710.0 | 907.0 | 210.0 | 89.0 | ||||
Sub-Saharan Africa | 2,950.0 | 589.8 | 341.0 | 25.7 | ||||
Kazakhstan | 149.0 | 41.1 | ||||||
Rest of Asia | 475.0 | 363.0 | 956.0 | 364.9 | ||||
Americas | 201.0 | 112.0 | 366.0 | 127.5 | ||||
Australia and Oceania | 7.0 | 3.8 | 14.0 | 3.3 | ||||
6,087.0 | 2,272.4 | 2,690.0 | 1,245.7 |
(a) Includes
temporary suspended wells pending further evaluation. (b) A dry well is an exploratory, development, or extension well that proves to be incapable of producing either oil or gas sufficient quantities to justify completion as an oil or gas well. (c) Includes 2,324 gross (799.1 net) multiple completion wells (more than one producing into the same well bore). Productive wells are producing wells and wells capable of production. One or more completions in the same bore hole are counted as one well. |
- 37 -
Eni Fact Book Gas & Power
Gas & Power |
Key performance indicators (*) |
2010 |
2011 |
2012 |
2013 |
2014 |
||||||||
Injury frequency rate of total Eni workforce | (No. of accidents per million of worked hours) | 3.98 | 3.04 | 2.23 | 1.43 | 0.49 | |||||||||||
Net sales from operations (a) | (euro million) | 27,806 | 33,093 | 36,198 | 32,212 | 28,250 | |||||||||||
Operating profit | 896 | (326 | ) | (3,125 | ) | (2,967 | ) | 186 | |||||||||
Adjusted operating profit | 1,268 | (247 | ) | 398 | (638 | ) | 310 | ||||||||||
Marketing | 923 | (657 | ) | 67 | (818 | ) | 155 | ||||||||||
International transport | 345 | 410 | 331 | 180 | 155 | ||||||||||||
Adjusted net profit | 1,267 | 252 | 479 | (253 | ) | 190 | |||||||||||
EBITDA pro-forma adjusted | 2,562 | 949 | 1,137 | (28 | ) | 760 | |||||||||||
Marketing | 1,863 | 257 | 631 | (346 | ) | 467 | |||||||||||
International transport | 699 | 692 | 506 | 318 | 293 | ||||||||||||
Capital expenditure | 265 | 192 | 213 | 229 | 172 | ||||||||||||
Worldwide gas sales (b) | (bcm) | 97.06 | 96.76 | 95.32 | 93.17 | 89.17 | |||||||||||
LNG sales (c) | 15.0 | 15.7 | 14.6 | 12.4 | 13.3 | ||||||||||||
Customers in Italy | (million) | 6.88 | 7.10 | 7.45 | 8.00 | 7.93 | |||||||||||
Electricity sold | (TWh) | 39.54 | 40.28 | 42.58 | 35.05 | 33.58 | |||||||||||
Employees at year end | (number) | 5,072 | 4,795 | 4,836 | 4,616 | 4,228 | |||||||||||
Direct GHG emissions | (mmtonnes CO2 eq) | 13.48 | 12.84 | 12.77 | 11.22 | 10.08 | |||||||||||
Customer satisfaction index (CSC) (d) | (%) | 87.4 | 88.6 | 89.7 | 92.9 | 93.4 | |||||||||||
Water consumption/withdrawals per kWh eq produced (EniPower) | (cm/kWh eq) | 0.013 | 0.014 | 0.012 | 0.017 | 0.017 | |||||||||||
(*)
Following the divestment of the Regulated Businesses in
Italy, results of the Gas & Power Division include
Marketing and International transport activities.
Reference periods have been restated accordingly. (a) Before elimination of intragroup sales. (b) Include volumes marketed by the Exploration & Production Division of 2.73 bcm (5.65, 2.86, 2.73 and 2.61 bcm in 2010, 2011, 2012 and 2013, respectively). (c) Refers to LNG sales of the Gas & Power Division (included in worldwide gas sales) and the Exploration & Production Division. (d) Data referred to the first half of 2014, as at the date of publication of this document Authority for Electricity Gas and Water (AEEGSI) has not still published the data for the second part of the year. |
Performance of the year
I In 2014, the positive trend in
employees and contractors injury frequency
rates was confirmed (down by 66%). I The water consumption rate of EniPowers plants decreased in absolute terms (down by 5.9% from 2013), while the same index per kWh produced was substantially stable. The decrease was due to lower use of sea water in cooling operations at Brindisi site. Despite the reduction of water consumption in absolute terms, generation of steam and freshwater consumption were essentially stable compared to 2013. I In 2014, adjusted net profit of the Gas & Power segment amounted to euro 190 million, up by euro 443 million from 2013. This reflected the benefits from the renegotiation of a substantial portion of the long-term gas supply portfolio, including greater one-off effects related to the purchase costs of volumes supplied in previous reporting periods. These positive effects were partially offset by declining gas and power prices against the backdrop of continuing weak demand and competitive pressure. |
I Renegotiation of long-term supply
contracts and take-or-pay reductions: gas prices and
related trends were better aligned to market conditions.
Approximately 70% of long-term gas supply portfolio is
now indexed to hub prices. Furthermore, the cash advances
paid to suppliers due to the take-or-pay clause were
reduced by euro 0.66 billion thanks also to sales
optimization. I Eni gas sales (89.17 bcm) were down by 4.3% compared to 2013. Enis sales in the domestic market of 34.04 bcm decreased by 5.1% driven by lower sales in all the business segments partially offset by higher spot sales. Barely unchanged volumes marketed in the main European markets (42.21 bcm; down by 1.1%). I Capital expenditure of euro 172 million mainly concerned the flexibility and upgrading of combined cycle power stations (euro 98 million), as well as gas marketing initiatives (euro 66 million). |
- 38 -
Eni Fact Book Gas & Power
Strategy | ||
In the Gas & Power segment, it is forecasted a structural decline in demand due to lower consumption driven by the macroeconomic crisis, competition of other sources, as well as a general oversupply situation in Europe, in the context of an increasing liquidity at hubs. Main target is the focus on profitability and sustainable cash flow, according the following guidelines: (i) complete alignment of supply portfolio to market conditions and substantial recovery of the residual amounts of gas paid in advance; (ii) simplification of operations and optimization of logistic costs with a saving of euro 300 million by 2018; and (iii) development and growth in the value added segments, in particular in the retail segment, developing the client base also through the sale of extracommodity products, trading, as well as in the LNG segment, leveraging on the marketing opportunities in premium markets and upstream integration. Cash flow from operations is expected to contribute for euro 3 billion cumulatively over the four-year plan. |
Gas
& Power value chain Enis Gas & Power segment engages in all phases of the natural gas value chain: supply, trading and marketing of natural gas and LNG. This segment also includes power generation and marketing of electricity. Enis leading position in the European gas market is ensured by a set of competitive advantages, including our multi-country approach, long-term gas availability, access to infrastructures, market knowledge and a strong customer base, in addition to long-term relations with producing countries. Furthermore, integration with our upstream operations provides valuables growth options whereby the Company targets to monetize its large gas reserves. |
- 39 -
Eni Fact Book Gas & Power
1. Marketing 1.1 Natural gas Supply |
92% of total supplies, down by 2.53 bcm, or 3.2% compared to the previous year, due to lower volumes purchased in particular in Russia (down 2.91 bcm), Algeria (down 1.80 bcm), Norway (down 0.73 bcm) and the United Kingdom (down 0.40 bcm), partly offset by higher volumes purchased in Libya (up 0.88 bcm) and the Netherlands (up 0.40 bcm). Supplies in Italy (6.92 bcm) registered a slight decrease from 2013 (down 0.23 bcm) due to mature fields decline. |
Marketing
in Italy and Europe Eni operates in a liberalized market where energy customers are allowed to choose the gas supplier and, according to their specific needs, to evaluate the quality of services and offers. Overall Eni supplies approximately 2,400 customers including large companies, power generation companies, wholesalers and distributors of natural gas for automotive use. Residential users are approximately 7.93 million amid households, professionals, small and medium-sized enterprises |
and public bodies located all over Italy, and approximately 2.2 million customers in European countries. In a trading environment characterized by a 12% drop of demand in the Italian market compared to the previous year (a similar decline was registered in the European Union) due to declining consumption in all the reference segments and raising competitive pressure, Eni carried out a number of initiatives such as renegotiation of supply contracts, efficiency and optimization actions in order to mitigate the negative impact of the reference scenario. |
- 40 -
Eni Fact Book Gas & Power
Sales and market shares by segment | (bcm) |
2013 |
2014 |
Volumes sold | Market share (%) | Volumes sold | Market share (%) | % Ch. 2014 vs. 2013 |
Italy to third parties | 29.93 | 42.7 | 28.42 | 46.3 | (5.0 | ) | |||||
Wholesalers | 4.58 | 4.05 | (11.6 | ) | |||||||
Italian gas exchange and spot markets | 10.68 | 11.96 | 12.0 | ||||||||
Industries | 6.07 | 4.93 | (18.8 | ) | |||||||
Medium-sized enterprises and services | 1.12 | 1.60 | 42.9 | ||||||||
Power generation | 2.11 | 1.42 | (32.7 | ) | |||||||
Residential | 5.37 | 4.46 | (16.9 | ) | |||||||
Own consumption | 5.93 | 5.62 | (5.2 | ) | |||||||
TOTAL SALES IN ITALY | 35.86 | 51.2 | 34.04 | 55.4 | (5.1 | ) | |||||
Gas demand (a) | 70.10 | 61.40 | (12.4 | ) | |||||||
(a) Source: Italian Ministry of Economic Development. |
Gas sales by market |
(bcm) | 2010 |
2011 |
2012 |
2013 |
2014 |
ITALY | 34.29 | 34.68 | 34.78 | 35.86 | 34.04 | |||||
Wholesalers | 4.84 | 5.16 | 4.65 | 4.58 | 4.05 | |||||
Gas release | 0.68 | |||||||||
Italian gas exchange and spot markets | 4.65 | 5.24 | 7.52 | 10.68 | 11.96 | |||||
Industries | 6.41 | 7.21 | 6.93 | 6.07 | 4.93 | |||||
Medium-sized enterprises and services | 1.09 | 0.88 | 0.81 | 1.12 | 1.60 | |||||
Power generation | 4.04 | 4.31 | 2.55 | 2.11 | 1.42 | |||||
Residential | 6.39 | 5.67 | 5.89 | 5.37 | 4.46 | |||||
Own consumption | 6.19 | 6.21 | 6.43 | 5.93 | 5.62 | |||||
INTERNATIONAL SALES | 62.77 | 62.08 | 60.54 | 57.31 | 55.13 | |||||
Rest of Europe | 54.52 | 52.98 | 51.02 | 47.35 | 46.22 | |||||
Importers in Italy | 8.44 | 3.24 | 2.73 | 4.67 | 4.01 | |||||
European markets | 46.08 | 49.74 | 48.29 | 42.68 | 42.21 | |||||
Iberian Peninsula | 7.11 | 7.48 | 6.29 | 4.90 | 5.31 | |||||
Germany/Austria | 5.67 | 6.47 | 7.78 | 8.31 | 7.44 | |||||
Benelux | 15.64 | 13.84 | 10.31 | 8.68 | 10.36 | |||||
Hungary | 2.36 | 2.24 | 2.02 | 1.84 | 1.55 | |||||
UK | 4.45 | 4.21 | 4.75 | 3.51 | 2.94 | |||||
Turkey | 3.95 | 6.86 | 7.22 | 6.73 | 7.12 | |||||
France | 6.09 | 7.01 | 8.36 | 7.73 | 7.05 | |||||
Other | 0.81 | 1.63 | 1.56 | 0.98 | 0.44 | |||||
Extra European markets | 2.60 | 6.24 | 6.79 | 7.35 | 5.85 | |||||
E&P in Europe and in the Gulf of Mexico | 5.65 | 2.86 | 2.73 | 2.61 | 3.06 | |||||
WORLDWIDE GAS SALES | 97.06 | 96.76 | 95.32 | 93.17 | 89.17 | |||||
A review of Enis presence in key European markets is presented below:
- 41 -
Eni Fact Book Gas & Power
Benelux Through a direct presence Eni holds a key position in the Benelux Countries (Belgium, the Netherlands and Luxembourg), in particular in Belgium, which are a strategic hub of the continental gas spot market in Western Europe, thanks to their geographical position and high level of interconnectivity with the gas transit networks of continental Europe. In 2014, sales in Benelux were mainly directed to industrial companies, wholesalers and power generation and amounted to 10.36 bcm, down by 1.68 bcm, or 19.4%, due to higher spot sales. Eni launched its brand in retail gas and power market in Belgium. The Eni brand substituted the brands of the local operators acquired in the past few years, with the aim of becoming one of the major retail operators in France and Belgium while consolidating its leadership on the Belgian business market. France Germany/Austria Spain Turkey United Kingdom |
the main continental natural
gas hubs (NBP, Zeebrugge, TTF). In 2014, sales amounted
to 2.94 bcm, with a decrease of 16.2% from a year ago. 1.2 LNG 1.3 Power generation Installed generation capacity as of December 31, 2014: 5,283 MW The combined cycle gas fired technology (CCGT) ensures an high level of efficiency and low environmental impact. In particular, management estimates that for a given amount of energy (electricity and steam) produced, using the CCGT technology instead of conventional power generation technology, the emission of carbon dioxide is reduced by about 5 mmtonnes, on an energy production of 26.5 TWh. |
- 42 -
Eni Fact Book Gas & Power
In 2014, power generation was 19.55 TWh, down by 1.83 TWh, or 8.6% from 2013, mainly due to lower production at Ravenna and Brindisi plants due to decreasing demand. As of December 31, 2014, installed | operational capacity was 4.9 GW (4.8 GW as of December 31, 2013). Electricity trading reported a slight increase (up 2.6% to 14.03 TWh ) mainly due to higher purchases on the spot market. |
2. International transport
Eni, as shipper, has
transport rights on a large European and North African
networks for transporting natural gas in Italy and
Europe, which link key consumption basins with the main
producing areas (Russia, Algeria, the North Sea,
including the Netherlands, Norway, and Libya). The
Company participates to both entities which operate the
pipelines and entities which manage transport rights. A
description of the main international pipelines currently
participated or operated by Eni is provided below: - the TTPC pipeline, 740-kilometer long, is made up of two lines that are each 370-kilometer long with a transport capacity of 33.2 bcm/y and five compression stations. This pipeline transports natural gas from Algeria across Tunisia from Oued Saf Saf at the Algerian border to Cap Bon on the Sicily Channel where it links with the TMPC pipeline; - the TMPC pipeline for the import of Algerian gas is 775-kilometer long and consists of five lines that are each 155-kilometer long with a |
transport capacity of 33.5
bcm/y. It crosses the Sicily Channel from Cap Bon to
Mazara del Vallo in Sicily, the point of entry into the
Italian natural gas transport system; - the Green Stream pipeline for the import of Libyan gas produced at the Eni operated fields of Bahr Essalam and Wafa. It is 520-kilometer long with a transport capacity of 8 bcm/y crossing the Mediterranean Sea from Mellitah on the Libyan coast to Gela in Sicily, the point of entry into the Italian natural gas transport system; and - Eni holds a 50% interest in the Blue Stream underwater pipeline (with a record water depth of more than 2,150 meters) linking the Russian coast to the Turkish coast of the Black Sea. This pipeline is 774-kilometer long on two lines and has transport capacity of 16 bcm/y. It is part of a joint venture to sell gas produced in Russia on the Turkish market. These assets generate a steady operating profit thanks to the sale of transport rights on a long-term basis. |
- 43 -
Eni Fact Book Gas & Power
Supply of natural gas |
(bcm) | 2010 |
2011 |
2012 |
2013 |
2014 |
Italy | 7.29 | 7.22 | 7.55 | 7.15 | 6.92 | ||||||||||
Outside Italy | |||||||||||||||
Russia | 14.29 | 21.00 | 19.83 | 29.59 | 26.68 | ||||||||||
Algeria (including LNG) | 16.23 | 13.94 | 14.45 | 9.31 | 7.51 | ||||||||||
Libya | 9.36 | 2.32 | 6.55 | 5.78 | 6.66 | ||||||||||
Netherlands | 10.16 | 11.02 | 11.97 | 13.06 | 13.46 | ||||||||||
Norway | 11.48 | 12.30 | 12.13 | 9.16 | 8.43 | ||||||||||
United Kingdom | 4.14 | 3.57 | 3.20 | 3.04 | 2.64 | ||||||||||
Hungary | 0.66 | 0.61 | 0.61 | 0.48 | 0.38 | ||||||||||
Qatar (LNG) | 2.90 | 2.90 | 2.88 | 2.89 | 2.98 | ||||||||||
Other supplies of natural gas | 4.42 | 6.16 | 5.43 | 3.63 | 5.56 | ||||||||||
Other supplies of LNG | 1.56 | 2.23 | 2.09 | 1.58 | 1.69 | ||||||||||
75.20 | 76.05 | 79.14 | 78.52 | 75.99 | |||||||||||
Total supplies of Enis own companies | 82.49 | 83.27 | 86.69 | 85.67 | 82.91 | ||||||||||
Offtake from (input to) storage | (0.20 | ) | 1.79 | (1.35 | ) | (0.58 | ) | (0.20 | ) | ||||||
Network losses, measurement differences and other changes | (0.11 | ) | (0.21 | ) | (0.28 | ) | (0.31 | ) | (0.25 | ) | |||||
AVAILABLE FOR SALE BY ENI'S CONSOLIDATED SUBSIDIARIES | 82.18 | 84.85 | 85.06 | 84.78 | 82.46 | ||||||||||
AVAILABLE FOR SALE BY ENI'S AFFILIATES | 9.23 | 9.05 | 7.53 | 5.78 | 3.65 | ||||||||||
E&P volumes in Europe and in the Gulf of Mexico | 5.65 | 2.86 | 2.73 | 2.61 | 3.06 | ||||||||||
GAS VOLUMES AVAILABLE FOR SALE | 97.06 | 96.76 | 95.32 | 93.17 | 89.17 |
Gas sales by entity |
(bcm) | 2010 |
2011 |
2012 |
2013 |
2014 |
Sales of consolidated companies | 82.00 | 84.05 | 84.30 | 83.60 | 81.73 | |||||
Italy (including own consumption) | 34.23 | 34.60 | 34.66 | 35.76 | 34.04 | |||||
Rest of Europe | 46.74 | 44.84 | 44.57 | 42.30 | 43.07 | |||||
Outside Europe | 1.03 | 4.61 | 5.07 | 5.54 | 4.62 | |||||
Sales of Enis affiliates (net to Eni) | 9.41 | 9.85 | 8.29 | 6.96 | 4.38 | |||||
Italy | 0.06 | 0.08 | 0.12 | 0.10 | ||||||
Rest of Europe | 7.78 | 8.14 | 6.45 | 5.05 | 3.15 | |||||
Outside Europe | 1.57 | 1.63 | 1.72 | 1.81 | 1.23 | |||||
E&P in Europe and in the Gulf of Mexico | 5.65 | 2.86 | 2.73 | 2.61 | 3.06 | |||||
Worldwide gas sales | 97.06 | 96.76 | 95.32 | 93.17 | 89.17 |
LNG sales |
(bcm) | 2010 |
2011 |
2012 |
2013 |
2014 |
G&P sales | 11.2 | 11.8 | 10.5 | 8.4 | 8.9 | |||||
Italy | 0.2 | |||||||||
Rest of Europe | 9.8 | 9.8 | 7.6 | 4.6 | 5.0 | |||||
Extra European markets | 1.2 | 2.0 | 2.9 | 3.8 | 3.9 | |||||
E&P sales | 3.8 | 3.9 | 4.1 | 4.0 | 4.4 | |||||
Liquefaction plants: | ||||||||||
Soyo (Angola) | 0.1 | 0.1 | ||||||||
Bontang (Indonesia) | 0.7 | 0.6 | 0.6 | 0.5 | 0.5 | |||||
Point Fortin (Trinidad & Tobago) | 0.6 | 0.4 | 0.5 | 0.6 | 0.6 | |||||
Bonny (Nigeria) | 2.2 | 2.5 | 2.7 | 2.4 | 2.8 | |||||
Darwin (Australia) | 0.3 | 0.4 | 0.3 | 0.4 | 0.4 | |||||
Total LNG sales | 15.0 | 15.7 | 14.6 | 12.4 | 13.3 |
- 44 -
Eni Fact Book Gas & Power
Electricity sales |
(TWh) | 2010 |
2011 |
2012 |
2013 |
2014 |
Free market | 27.84 | 27.25 | 31.84 | 28.73 | 24.86 | |||||
Italian Power Exchange | 7.13 | 8.67 | 6.10 | 1.96 | 4.71 | |||||
Industrial plants | 3.21 | 3.23 | 3.30 | 3.31 | 3.17 | |||||
Other (a) | 1.36 | 1.13 | 1.34 | 1.05 | 0.84 | |||||
Power sales | 39.54 | 40.28 | 42.58 | 35.05 | 33.58 | |||||
Power generation | 25.63 | 25.23 | 23.58 | 21.38 | 19.55 | |||||
Trading of electricity (a) | 13.91 | 15.05 | 19.00 | 13.67 | 14.03 |
(a)
Include positive and negative imbalances. |
EniPower power stations | Installed capacity as of December 31, 2014 (a) | Effective/planned start-up | Technology | Fuel |
Power stations | (MW) | |||||||
Brindisi | 1,321 | 2006 | CCGT | gas | ||||
Ferrera Erbognone | 1,030 | 2004 | CCGT | gas/syngas | ||||
Livorno | 199 | 2000 | Power Station | gas/fuel oil | ||||
Mantova | 850 | 2005 | CCGT | gas | ||||
Ravenna | 972 | 2004 | CCGT | gas | ||||
Ferrara (b) | 841 | 2008 | CCGT | gas | ||||
Bolgiano | 60 | 2012 | Power Station | gas | ||||
Photovoltaic sites | 10 | 2011-2015 | Photovoltaic | Photovoltaic | ||||
5,283 |
(a) Capacity available
after completion of dismantling of obsolete plants. (b) Enis share of capacity.1 |
EniPower power stations |
2010 |
2011 |
2012 |
2013 |
2014 |
Purchases | ||||||||||||
Purchases of natural gas | (mmcm) | 5,154 | 5,008 | 4,792 | 4,295 | 4,074 | ||||||
Purchases of other fuels | (ktoe) | 547 | 528 | 462 | 449 | 338 | ||||||
- of which steam cracking | 103 | 99 | 98 | 99 | 104 | |||||||
Production | ||||||||||||
Power generation | (TWh) | 25.63 | 25.23 | 23.58 | 21.38 | 19.55 | ||||||
Steam generation | (ktonnes) | 10,983 | 14,401 | 12,603 | 9,907 | 9,010 | ||||||
Installed generation capacity (in operation) | (GW) | 5.3 | 5.3 | 5.3 | 4.8 | 4.9 |
Transport infrastructure |
Route | Lines |
Length |
Diameter |
Transport
capacity (a) |
Transit
capacity (b) |
Compression
stations |
||||||
TTPC (Oued Saf Saf-Cap Bon) | 2 lines of km 370 | 740 | 48 | 34.0 | 33.2 | 5 | ||||||
TMPC (Cap Bon-Mazara del Vallo) | 5 lines of km 155 | 775 | 20/26 | 33.5 | 33.5 | |||||||
GreenStream (Mellitah-Gela) | 1 line of km 520 | 520 | 32 | 8.0 | 8.0 | 1 | ||||||
Blue Stream (Beregovaya-Samsun) | 2 lines of km 387 | 774 | 24 | 16.0 | 16.0 | 1 | ||||||
(a) Includes both transit
capacity and volumes of natural gas destined to local
markets and withdrawn at different points along the
pipeline. (b) The maximum volume of natural gas coming from different entry points along the pipeline and transported to the next pipeline. |
Capital expenditure |
(euro million) | 2010 |
2011 |
2012 |
2013 |
2014 |
Italy | 155 | 132 | 166 | 161 | 128 | |||||
Outside Italy | 110 | 60 | 47 | 68 | 44 | |||||
265 | 192 | 213 | 229 | 172 | ||||||
Market | 248 | 184 | 200 | 206 | 164 | |||||
Market | 133 | 97 | 77 | 87 | 66 | |||||
Italy | 40 | 45 | 43 | 42 | 30 | |||||
Outside Italy | 93 | 52 | 34 | 45 | 36 | |||||
Power generation | 115 | 87 | 123 | 119 | 98 | |||||
International transport | 17 | 8 | 13 | 23 | 8 | |||||
265 | 192 | 213 | 229 | 172 |
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Eni Fact Book Refining & Marketing
Refining & Marketing |
Key performance indicators |
2010 |
2011 |
2012 |
2013 |
2014 |
||||||||
Injury frequency rate of total Eni workforce | (No. of accidents per million of worked hours) | 2.56 | 2.60 | 1.74 | 1.01 | 0.86 | |||||||||||
Net sales from operations (a) | (euro million) | 43,190 | 51,219 | 62,531 | 57,238 | 56,153 | |||||||||||
Operating profit | 149 | (273 | ) | (1,264 | ) | (1,492 | ) | (2,229 | ) | ||||||||
Adjusted operating profit | (181 | ) | (539 | ) | (289 | ) | (457 | ) | (208 | ) | |||||||
Adjusted net profit | (56 | ) | (264 | ) | (181 | ) | (232 | ) | (147 | ) | |||||||
Capital expenditure | 711 | 866 | 898 | 672 | 537 | ||||||||||||
Refinery throughputs on own account | (mmtonnes) | 34.80 | 31.96 | 30.01 | 27.38 | 25.03 | |||||||||||
Conversion index | (%) | 61 | 61 | 61 | 62 | 51 | |||||||||||
Balanced capacity of refineries | (kbbl/d) | 757 | 767 | 767 | 787 | 617 | |||||||||||
Retail sales of petroleum products in Europe | (mmtonnes) | 11.73 | 11.37 | 10.87 | 9.69 | 9.21 | |||||||||||
Service stations in Europe at year end | (units) | 6,167 | 6,287 | 6,384 | 6,386 | 6,220 | |||||||||||
Average throughput per service station in Europe | (kliters) | 2,353 | 2,206 | 2,064 | 1,828 | 1,725 | |||||||||||
Retail efficiency index | (%) | 1.53 | 1.50 | 1.48 | 1.28 | 1.19 | |||||||||||
Employees at year end | (number) | 8,022 | 7,591 | 8,608 | 8,438 | 6,774 | |||||||||||
Direct GHG emissions | (mmtonnes CO2 eq) | 7.85 | 7.28 | 6.06 | 5.20 | 5.34 | |||||||||||
SOx (sulphur oxide) emissions | (ktonnes SO2 eq) | 28.05 | 23.07 | 16.99 | 10.80 | 6.09 | |||||||||||
Water consumption rate (refineries)/refinery throughputs | (cm/tonnes) | 28.36 | 31.03 | 25.43 | 19.98 | 22.42 | |||||||||||
Biofuels marketed | (mmtonnes) | 17.79 | 13.26 | 14.83 | 10.84 | 12.93 | |||||||||||
Customer satisfaction index | (likert scale) | 7.84 | 7.74 | 7.90 | 8.10 | 8.20 | |||||||||||
(a) Before elimination of intragroup sales. |
Performance of the year
I In 2014, continued the positive trend in
injury frequency rate for employees and contractors (down
by 14.9%). I In 2014, the Refining & Marketing segment reduced the adjusted net loss to euro 147 million (euro 232 million in 2013) driven by improved refining margins, reflecting a fall in oil prices in the last quarter of the year and restructuring initiatives, including the start-up of the Green Refinery project in Venice, as well as cost efficiency initiatives, particularly with respect to energy and overhead costs. I In 2014, refining throughputs were 25.03 mmtonnes, down by 8.6% from 2013. In Italy, processed volumes decreased by 11.7% mainly due to the unfavorable refinery scenario registered in the first part of the year, as well as the shutdown of the Gela and Venice refineries due to the ongoing reconversion activities. I In 2014, the production of biofuels amounted to 12.93 mmtonnes, up by 19.3% compared to a year ago following the start-up of the bio-refinery in Porto Marghera. |
I Retail sales in Italy amounted to 6.14
mmtonnes, down by 7.5% from 2013 due to strong
competitive pressure. In 2014, Enis average retail
market share was 25.5%, down by 2 percentage points from
2013. I Retail sales in the rest of Europe of 3.07 mmtonnes were substantially stable compared to 2013 (up by 0.7%). Higher volumes marketed in Germany and Austria were offset by lower sales of the other subsidiaries. I Capital expenditure amounting to euro 537 million mainly related to the reconversion of the Venice site to bio-refinery, as well as maintenance and improvement of flexibility and yields of the other plants, in particular at Sannazzaro refinery (euro 362 million) and marketing activities for the rebranding of the retail distribution network (euro 175 million). I In 2014, the expenditure in R&D in the Refining & Marketing segment amounted to approximately euro 18 million. During the year 15 patent applications were filed. |
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Eni Fact Book Refining & Marketing
Portfolio rationalization In line with the Enis strategy focused on selectively growing in high profitable markets, Eni signed a preliminary agreement for the divestment of its marketing activities of fuels located in Czech Republic, Slovakia and Romania. The agreement also comprises the refinery capacity to supply the marketing network through a 32.445% interest in the joint refining asset Ceská Rafinérská as (CRC). All these agreements are subject to the approval of the relevant European Antitrust Authorities. Relaunch plan of the Gela site In November 2014, Eni defined with the Ministry for Economic Development, the Region of Sicily and interested stakeholders a plan to restore the profitability of the Gela refinery. The key point of the agreement is the reconversion of the Gela site to a bio-refinery. The reconversion will follow the model adopted for the Venice green |
refinery, where green diesel
is produced from raw vegetable materials by using the
proprietary EcofiningTM technology. The
agreement also defines terms for building a modern
logistic hub and new initiatives in the upstream sector
in Sicily, including offshore. Eni will also perform
environmental remediation and clean-up activities and
institute the Safety Competence Center (SCC), a center of
excellence in the security field. The investment plan for
such initiatives amounts to euro 2.2 billion, mainly
relating to upstream projects in the Sicily region. Start-up of Venice bio-refinery In June 2014, the start-up of the bio-refinery of Porto Marghera was achieved, with a green diesel capacity of approximately 300 ktonnes/y. The green diesel is produced from refined vegetable oil utilizing the proprietary EcofiningTM technology. The production will fulfill half of the Enis annual requirement of green diesel, thus ensuring new perspectives for the industrial site of Venice and allowing economic and environmental benefits. |
|
Strategy | ||
For the next four years, the priority for the Refining & Marketing segment is the return to profitability in the context of weak fundamentals of the European refining market, affected by structural overcapacity. Eni intends to reduce refining exposure, through the reconversion of productive processes by the achievement of the breakeven level of adjusted operating profit and of cash flow from 2015 leveraging on: (i) rationalization of refining capacity and reconversion of industrial plants in Italy and abroad, reducing capacity by a further 20% in addition to the 30% capacity downsizing reached up to 2014; (ii) continuous efficiency improvement; and (iii) marketing activities development and rationalization of our portfolio in Italy and abroad. We believe that those actions will reduce our breakeven in the refining business to approximately 3 $/bbl at the end of the plan. |
Activities 1. Refining Eni, through its Refining & Marketing segment, is a leader in refining in Italy, with its five wholly-owned refineries (Sannazzaro, Livorno, Venice, Taranto and Gela), and in marketing of petroleum products. |
In the rest of Europe Eni also holds interests in certain refining poles and is active in retail and wholesale sales in Central-Eastern European countries. Enis refining system has balanced capacity of approximately 30.8 mmtonnes (equal to 617 kbbl/d) and a conversion index of 62%. |
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Eni Fact Book Refining & Marketing
In 2014, total refinery
throughputs were 25.03 mmtonnes, of which 19.92 mmtonnes
in Italy and 5.11 outside Italy. Total throughputs in
wholly-owned refineries were 16.24 mmtonnes, down by 2.75
mmtonnes or 14.5% from 2013. This determined a refinery
utilization rate of 78%, calculated as the average
Enis refineries complexity and their utilization
rate. Approximately 25.2% of processed volumes were supplied by Enis Exploration & Production segment, up by 1.5 percentage points from 2013 (23.7%). n Italy |
at maximizing the value
associated to the asset structure, the geographic
location with respect to end markets, the integration
with Enis other activities, as well as the
development of green technologies. Sannazzaro: refinery has balanced refining capacity of 200 kbbl/d and a conversion index of 70.2%. Management believes that this site is one of the most efficient refineries in Europe. Located in the Po Valley, it mainly supplies markets in North-Western Italy and Switzerland. The high flexibility and conversion capacity of this refinery allows it to process a wide range of feedstock. From a logistical standpoint this refinery is located along the route of the Central Europe pipeline, which links the Genoa terminal with French speaking Switzerland. This refinery contains two primary distillation |
Crude oil that needs to be carried to the refinery by means of pipelines or over long distances by tanker ships undergoes processing for the separation of its components. In refineries crude oil is warmed to a temperature of approximately 400°C so that it turns into vapor. Oil vapors are injected in fractionating columns, also called distillation towers, where they flow upward through a series of plates and cool. At various temperatures they condense and return to a liquid state. While cooling and falling they separate in various hydrocarbon fractions (gasoil, kerosene, naphtha, gasoline, methane, ethane, propane and butane, fuel oil, lubricants, paraffin, wax and bitumen). |
Refining system in 2014 |
Ownership
share (%) |
Distillation
capacity (total) (kbbl/d) |
Distillation
capacity (Enis share) (kbbl/d) |
(a)
(kbbl/d) |
Conversion
index (%) |
Fluid
catalytic cracking - FCC (kbbl/d) |
Residue
conversion (kbbl/d) |
Go-Finer/ (kbbl/d) |
Mild
Hydro- cracking/ Hydro- cracking (kbbl/d) |
Visbreaking/
Thermal Cracking (kbbl/d) |
Coking (kbbl/d) |
Distillation
capacity utilization rate (Enis share) (%) |
Balanced
refining capacity utilization rate (Enis share) (%) |
||||||||||||||
Wholly-owned refineries | 449 | 449 | 404 | 54 | 34 | 35 | 0 | 66 | 67 | 0 | 72 | 78 | ||||||||||||||
Italy | ||||||||||||||||||||||||||
Sannazzaro | 100 | 223 | 223 | 200 | 70 | 34 | 13 | 51 | 29 | 75 | 83 | |||||||||||||||
Gela | 100 | |||||||||||||||||||||||||
Taranto | 100 | 120 | 120 | 120 | 56 | 22 | 15 | 38 | 62 | 62 | ||||||||||||||||
Livorno | 100 | 106 | 106 | 84 | 11 | 71 | 90 | |||||||||||||||||||
Porto Marghera | 100 | |||||||||||||||||||||||||
Partially-owned refineries (b) | 874 | 245 | 213 | 47 | 167 | 25 | 99 | 27 | 85 | 88 | ||||||||||||||||
Italy | ||||||||||||||||||||||||||
Milazzo | 50 | 248 | 124 | 100 | 60 | 45 | 25 | 32 | 80 | 85 | ||||||||||||||||
Germany | ||||||||||||||||||||||||||
Vohburg/Neustadt (Bayernoil) |
20 | 215 | 43 | 41 | 36 | 49 | 43 | 91 | 91 | |||||||||||||||||
Schwedt | 8.33 | 231 | 19 | 19 | 42 | 49 | 27 | 102 | 102 | |||||||||||||||||
Czech Republic | ||||||||||||||||||||||||||
Kralupy
e Litvinov (Ceská Rafinérská) |
32.4 | 180 | 58 | 53 | 30 | 24 | 24 | 87 | 87 | |||||||||||||||||
TOTAL | 1,323 | 694 | 617 | 51 | 201 | 60 | 0 | 165 | 94 | 0 | 75 | 82 |
(a) Actual production capacity: Venice conversion in "Green Refinery"; Gela shutdown in HUB crudes asset. (b) Capacity of conversion plant is 100%. |
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Eni Fact Book Refining & Marketing
plants and relevant
facilities, including three desulphurization units.
Conversion is obtained through a fluid catalytic cracker
(FCC), two hydrocrackers (HDC), the last unit entered
into operations in June 2009, which enable middle
distillate conversion and a visbreaking thermal
conversion unit with a gasification facility loaded with
heavy residue from visbreaking unit (tar) to produce
syn-gas to feed the nearby EniPower power plant at
Ferrera Erbognone. In 2013, the Eni Slurry Technology
(EST) project was started up. The conversion plant with a
23 kbbl/d capacity is designed to process extra heavy
crude with high sulphur content increasing yields in
middle distillates and reducing that of fuel oil. Eni is
also developing an upgrading of its conversion technology
called Slurry Dual-Catalyst (an evolution of EST), which
is based on a combination of two nano-catalysts and aims
at increasing productivity and improving product quality,
reducing expenditure and operating costs. A further
project underway is the proprietary process for hydrogen
production, Hydrogen SCT-CPO (Short Contact
Time-Catalytic Partial Oxidation). This reforming
technology transforms gaseous and liquid hydrocarbons
(also derived from bio-mass) into synthetic gas (carbon
monoxide and hydrogen) at competitive costs. Taranto: refinery has balanced refining capacity of 120 kbbl/d and a conversion index of 56%. This refinery processes most of oil produced in Enis Val dAgri fields carried to Taranto through the Monte Alpi pipeline (in 2014 a total of 2.91 mmtonnes of this oil was processed). It principally produces fuels for automotive use and residential heating purposes for the Southern Italian markets. The complexity is achieved through a Residue Hydroconversion Unit (RHU)-Hydrocracking process and a "Two Stage" Visbreaking-Thermal Cracking unit. Gela: the refinery was shut down in order to activate the plan of reconversion in bio-refinery following the model adopted for the Venice green refinery and create a logistic hub. |
Livorno:
refinery, with balanced refining capacity of 84 kbbl/d
and a conversion index of 11%, manufactures mainly
gasoline, fuel oil for bunkering and lubricant bases.
Besides its primary distillation plants, this refinery
contains two lubricant manufacturing lines. Its
infrastructures including highways, railways and pipeline
connecting the site with the local harbor and with the
Florence storage sites through two pipelines optimizing
intake, handling and distribution of products. Venice (Porto Marghera): in June 2014, the start up of the bio-refinery of Porto Marghera was achieved, with green diesel capacity of approximately 300 ktonnes/y. The green diesel is produced from refined vegetable oil utilizing the proprietary EcofiningTM technology. The production will fulfill half of the Enis annual requirement of green diesel, thus ensuring new perspectives for the industrial site of Venice and allowing economic and environmental benefits. Milazzo: jointly-owned by Eni and Kuwait Petroleum Italy, the refinery has balanced primary refining capacity of 124 kbbl/d (Enis share) and a conversion rate of 60%. Located on the Northern coast of Sicily, it is provided with two primary distillation plants, one unit of fluid catalytic cracking (FCC), one hydrocracking unit for the conversion of middle distillates (HDCK) and one unit devoted to the residue treatment process (LC-Finer). n Outside Italy |
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Eni Fact Book Refining & Marketing
2. Logistics Eni is a
primary operator in storage and transport of petroleum
products in Italy with its logistical integrated
infrastructure consisting of 18 directly managed storage
sites and a network of petroleum product pipelines for
products sale and storage of LPG and crude. Enis
logistic model is based on a hub structure covering five
main areas. These hubs monitor and centralize product
flows in order to lower collection and delivery costs.
Eni holds five partnerships with major Italian operators
located in the Vado Ligure-Genoa (Petrolig), Arquata
Scrivia (Sigemi), Venice (Petroven), Ravenna (Petra) and
Trieste (DCT) sites, they reduce logistic costs, and
increase efficiency. 3. Marketing n Retail sales in Italy In 2014, retail sales in Italy of 6.14 mmtonnes
decreased by approximately 0.50 mmtonnes, or by 7.5%
compared to 2013, driven by lower consumption of all
products amidst weak demand. Average gasoline and gasoil
throughput (1,534 kliters) decreased by approximately 124
kliters from 2013. |
n Retail Rest of Europe |
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Eni Fact Book Refining & Marketing
4. Wholesale business Fuels In 2014, sales volumes on wholesale markets in Italy (7.57 mmtonnes) declined by approximately 800 ktonnes, down by 9.6%, mainly due to lower sales of all products, in particular gasoil for heating reflecting the mild climate registered in the period, as well as fuel oil and bunkering due to declining demand. Average market share in 2014 was 26.7% (28.8% in 2013). Supplies to the petrochemical industry (0.97 mmtonnes) decreased from 2013 (down by 350 ktonnes) due to lower feedstock supplies. Wholesale sales in the Rest of Europe of approximately 4.60 mmtonnes increased by 8.7% from 2013 due to increased sales in Czech Republic, Hungary and France. Other sales (21.63 mmtonnes) increased by 2.18 mmtonnes, or 11.2%, mainly due to higher sales to the other oil companies. Eni also markets jet fuel directly at 51 airports, of which 30 are in Italy. In 2014, these sales amounted to 2.1 mmtonnes (of which 1.6 mmtonnes are in Italy). Eni is also active in the international market of bunkering, marketing marine fuel, mainly in 115 ports, of which 65 are in Italy. In 2014, marine fuel sales were 1.38 mmtonnes (1.26 mmtonnes in Italy). LPG |
channels mainly to oil
companies and traders. LPG activities in Italy are
supported by direct production, availability from 5
bottling plants and 1 owned storage site, in addition to
products imported at coastal storage sites located in
Livorno, Naples and Ravenna. Outside Italy, LPG sales in 2014 amounted to 549 ktonnes of which 410 ktonnes in Ecuador where LPG market share is approximately 37.9%. Lubricants Oxygenates |
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Eni Fact Book Refining & Marketing
Supply of oil |
(mmtonnes) | 2010 |
2011 |
2012 |
2013 |
2014 |
Equity crude oil | |||||||||||||||
Production outside Italy | 26.90 | 24.29 | 23.57 | 22.46 | 23.66 | ||||||||||
Production in Italy | 3.24 | 3.35 | 3.35 | 3.69 | 3.81 | ||||||||||
30.14 | 27.64 | 26.92 | 26.15 | 27.47 | |||||||||||
Other crudes oil | |||||||||||||||
Purchases on spot markets | 20.95 | 20.44 | 24.95 | 25.27 | 25.60 | ||||||||||
Purchases under forward contracts | 17.16 | 10.94 | 10.34 | 14.54 | 17.07 | ||||||||||
38.11 | 31.38 | 35.29 | 39.81 | 42.67 | |||||||||||
Total crude oil purchases | 68.25 | 59.02 | 62.21 | 65.96 | 70.14 | ||||||||||
Purchases of intermediate products | 3.05 | 4.26 | 4.53 | 5.31 | 4.94 | ||||||||||
Purchase of products | 15.28 | 15.85 | 20.52 | 17.79 | 20.87 | ||||||||||
TOTAL PURCHASES | 86.58 | 79.13 | 87.26 | 89.06 | 95.95 | ||||||||||
Consumption for power generation | (0.92 | ) | (0.89 | ) | (0.75 | ) | (0.55 | ) | (0.57 | ) | |||||
Other changes (a) | (2.69 | ) | (1.12 | ) | (1.63 | ) | (1.06 | ) | (0.98 | ) | |||||
82.97 | 77.12 | 84.89 | 87.45 | 94.40 |
(a) Include changes in inventories, transport declines, consumption and losses. |
Refinery capacity |
2010 |
2011 |
2012 |
2013 |
2014 |
Primary distillation capacity (a) | (kbbl/d) | 930 | 930 | 930 | 930 | 694 | ||||||
Balanced capacity (a) | 757 | 767 | 767 | 787 | 617 | |||||||
Refinery throughputs on own account | 514 | 455 | 417 | 380 | 317 | |||||||
Distillation capacity utilization rate | (%) | 73 | 72 | 72 | 66 | 75 |
(a) Enis share. |
Availability of refined products |
(mmtonnes) | 2010 |
2011 |
2012 |
2013 |
2014 |
ITALY | |||||||||||||||
At wholly-owned refineries | 25.70 | 22.75 | 20.84 | 18.99 | 16.24 | ||||||||||
Less input on account of third parties | (0.50 | ) | (0.49 | ) | (0.47 | ) | (0.57 | ) | (0.58 | ) | |||||
At affiliate refineries | 4.36 | 4.74 | 4.52 | 4.14 | 4.26 | ||||||||||
Refinery throughputs on own account | 29.56 | 27.00 | 24.89 | 22.56 | 19.92 | ||||||||||
Consumption and losses | (1.69 | ) | (1.55 | ) | (1.34 | ) | (1.23 | ) | (1.33 | ) | |||||
Products available for sale | 27.87 | 25.45 | 23.55 | 21.33 | 18.59 | ||||||||||
Purchases of refined products and change in inventories | 4.24 | 3.22 | 3.35 | 4.42 | 5.38 | ||||||||||
Products transferred to operations outside Italy | (4.18 | ) | (1.77 | ) | (2.36 | ) | (1.85 | ) | (0.64 | ) | |||||
Consumption for power generation | (0.92 | ) | (0.89 | ) | (0.75 | ) | (0.55 | ) | (0.57 | ) | |||||
Sales of products | 27.01 | 26.01 | 23.79 | 23.35 | 22.76 | ||||||||||
OUTSIDE ITALY | |||||||||||||||
Refinery throughputs on own account | 5.24 | 4.96 | 5.12 | 4.82 | 5.11 | ||||||||||
Consumption and losses | (0.24 | ) | (0.23 | ) | (0.23 | ) | (0.22 | ) | (0.21 | ) | |||||
Products available for sale | 5.00 | 4.73 | 4.89 | 4.60 | 4.90 | ||||||||||
Purchases of finished products and change in inventories | 10.61 | 12.51 | 17.29 | 13.69 | 16.11 | ||||||||||
Products transferred from Italian operations | 4.18 | 1.77 | 2.36 | 1.85 | 0.64 | ||||||||||
Sales of products | 19.79 | 19.01 | 24.54 | 20.14 | 21.65 | ||||||||||
Refinery throughputs on own account | 34.80 | 31.96 | 30.01 | 27.38 | 25.03 | ||||||||||
Total equity crude input | 5.02 | 6.54 | 6.39 | 5.93 | 5.81 | ||||||||||
Total sales of refined products | 46.80 | 45.02 | 48.33 | 43.49 | 44.41 | ||||||||||
Crude oil sales | 36.17 | 32.10 | 36.56 | 43.96 | 49.99 | ||||||||||
TOTAL SALES | 82.97 | 77.12 | 84.89 | 87.45 | 94.40 |
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Eni Fact Book Refining & Marketing
Production and sales |
(mmtonnes) | 2010 |
2011 |
2012 |
2013 |
2014 |
Products: | ||||||||||
Gasoline | 7.81 | 7.24 | 6.88 | 6.17 | 6.07 | |||||
Gasoil | 13.63 | 12.95 | 12.24 | 11.31 | 10.31 | |||||
Jet fuel/kerosene | 1.46 | 1.41 | 1.35 | 1.41 | 1.45 | |||||
Fuel oil | 3.75 | 2.65 | 2.77 | 2.40 | 2.04 | |||||
LPG | 0.50 | 0.57 | 0.51 | 0.50 | 0.49 | |||||
Lubricants | 0.67 | 0.54 | 0.62 | 0.60 | 0.54 | |||||
Petrochemical feedstock | 2.59 | 2.49 | 2.06 | 2.08 | 1.67 | |||||
Other | 2.46 | 2.33 | 2.00 | 1.46 | 0.92 | |||||
Total products | 32.87 | 30.18 | 28.43 | 25.93 | 23.49 | |||||
Sales: | ||||||||||
Italy | 27.01 | 26.01 | 23.79 | 23.35 | 22.76 | |||||
Gasoline | 2.91 | 2.78 | 2.61 | 2.21 | 2.00 | |||||
Gasoil | 9.94 | 9.63 | 9.14 | 8.42 | 7.61 | |||||
Jet fuel/kerosene | 1.45 | 1.64 | 1.56 | 1.58 | 1.59 | |||||
Fuel oil | 0.44 | 0.46 | 0.33 | 0.24 | 0.12 | |||||
LPG | 0.59 | 0.60 | 0.61 | 0.62 | 0.59 | |||||
Lubricants | 0.11 | 0.10 | 0.10 | 0.09 | 0.09 | |||||
Petrochemical feedstock | 1.72 | 1.71 | 1.26 | 1.32 | 0.97 | |||||
Other | 9.85 | 9.09 | 8.18 | 8.87 | 9.79 | |||||
Rest of Europe | 16.66 | 15.88 | 16.08 | 16.82 | 18.76 | |||||
Gasoline | 1.85 | 1.79 | 1.81 | 1.73 | 1.80 | |||||
Gasoil | 3.95 | 3.71 | 3.96 | 4.23 | 4.48 | |||||
Jet fuel/kerosene | 0.38 | 0.48 | 0.44 | 0.49 | 0.55 | |||||
Fuel oil | 0.25 | 0.23 | 0.19 | 0.22 | 0.18 | |||||
LPG | 0.12 | 0.12 | 0.13 | 0.12 | 0.14 | |||||
Lubricants | 0.10 | 0.09 | 0.08 | 0.08 | 0.09 | |||||
Other | 10.01 | 9.46 | 9.47 | 9.95 | 11.52 | |||||
Extra Europe | 3.13 | 3.13 | 8.46 | 3.32 | 2.89 | |||||
Gasoline | 2.74 | 2.62 | 8.00 | 1.55 | 2.23 | |||||
LPG | 0.37 | 0.38 | 0.39 | 0.39 | 0.41 | |||||
Lubricants | 0.02 | 0.02 | 0.01 | 0.02 | 0.01 | |||||
Other | 0.00 | 0.11 | 0.06 | 1.36 | 0.24 | |||||
Worldwide | ||||||||||
Gasoline | 7.50 | 7.19 | 12.42 | 5.49 | 6.03 | |||||
Gasoil | 13.89 | 13.34 | 13.10 | 12.65 | 12.09 | |||||
Jet fuel/kerosene | 1.83 | 2.12 | 2.00 | 2.07 | 2.14 | |||||
Fuel oil | 0.69 | 0.69 | 0.52 | 0.46 | 0.30 | |||||
LPG | 1.08 | 1.10 | 1.13 | 1.13 | 1.14 | |||||
Lubricants | 0.23 | 0.21 | 0.19 | 0.19 | 0.19 | |||||
Petrochemical feedstock | 1.72 | 1.71 | 1.26 | 1.32 | 0.97 | |||||
Other | 19.86 | 18.66 | 17.71 | 20.18 | 21.55 | |||||
TOTAL SALES | 46.80 | 45.02 | 48.33 | 43.49 | 44.41 |
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Eni Fact Book Refining & Marketing
Sales in Italy and outside Italy by market |
(mmtonnes) | 2010 |
2011 |
2012 |
2013 |
2014 |
Retail | 8.63 | 8.36 | 7.83 | 6.64 | 6.14 | |||||
Wholesale | 9.45 | 9.36 | 8.62 | 8.37 | 7.57 | |||||
18.08 | 17.72 | 16.45 | 15.01 | 13.71 | ||||||
Petrochemicals | 1.72 | 1.71 | 1.26 | 1.32 | 0.97 | |||||
Other sales | 7.21 | 6.58 | 6.08 | 7.01 | 8.08 | |||||
Sales in Italy | 27.01 | 26.01 | 23.79 | 23.34 | 22.76 | |||||
Retail rest of Europe | 3.10 | 3.01 | 3.04 | 3.05 | 3.07 | |||||
Wholesale rest of Europe | 3.88 | 3.84 | 3.96 | 4.23 | 4.60 | |||||
Wholesale outside Europe | 0.42 | 0.43 | 0.42 | 0.43 | 0.43 | |||||
Retail and wholesale outside Italy | 7.40 | 7.28 | 7.42 | 7.71 | 8.10 | |||||
Other markets | 12.39 | 11.73 | 17.12 | 12.44 | 13.55 | |||||
Sales outside Italy | 19.79 | 19.01 | 24.54 | 20.15 | 21.65 | |||||
TOTAL SALES | 46.80 | 45.02 | 48.33 | 43.49 | 44.41 |
Retail and wholesale sales of refined products |
(mmtonnes) | 2010 |
2011 |
2012 |
2013 |
2014 |
Italy | 18.08 | 17.72 | 16.45 | 15.01 | 13.71 | |||||
Retail sales | 8.63 | 8.36 | 7.83 | 6.64 | 6.14 | |||||
Gasoline | 2.76 | 2.60 | 2.41 | 1.96 | 1.71 | |||||
Gasoil | 5.58 | 5.45 | 5.08 | 4.33 | 4.07 | |||||
LPG | 0.26 | 0.29 | 0.31 | 0.32 | 0.32 | |||||
Other | 0.03 | 0.02 | 0.03 | 0.03 | 0.04 | |||||
Wholesale sales | 9.45 | 9.36 | 8.62 | 8.37 | 7.57 | |||||
Gasoil | 4.36 | 4.18 | 4.07 | 4.09 | 3.54 | |||||
Fuel oil | 0.44 | 0.46 | 0.33 | 0.24 | 0.12 | |||||
LPG | 0.33 | 0.31 | 0.30 | 0.30 | 0.28 | |||||
Gasoline | 0.16 | 0.19 | 0.20 | 0.25 | 0.30 | |||||
Lubricants | 0.10 | 0.10 | 0.09 | 0.09 | 0.09 | |||||
Bunker | 1.35 | 1.26 | 1.19 | 1.00 | 0.91 | |||||
Jet fuel | 1.46 | 1.65 | 1.56 | 1.58 | 1.59 | |||||
Other | 1.25 | 1.21 | 0.88 | 0.82 | 0.74 | |||||
Outside Italy (retail + wholesale) | 7.40 | 7.28 | 7.42 | 7.71 | 8.10 | |||||
Gasoline | 1.85 | 1.79 | 1.81 | 1.73 | 1.80 | |||||
Gasoil | 3.95 | 3.82 | 3.96 | 4.23 | 4.48 | |||||
Jet fuel | 0.40 | 0.49 | 0.44 | 0.51 | 0.56 | |||||
Fuel oil | 0.25 | 0.23 | 0.19 | 0.22 | 0.18 | |||||
Lubricants | 0.10 | 0.10 | 0.09 | 0.10 | 0.10 | |||||
LPG | 0.49 | 0.50 | 0.52 | 0.51 | 0.55 | |||||
Other | 0.36 | 0.35 | 0.41 | 0.41 | 0.43 | |||||
TOTAL | 25.48 | 25.00 | 23.87 | 22.72 | 21.81 |
Number of service stations |
(units) | 2010 |
2011 |
2012 |
2013 |
2014 |
Italy | 4,542 | 4,701 | 4,780 | 4,762 | 4,592 | |||||||
Ordinary stations | 4,415 | 4,574 | 4,653 | 4,636 | 4,468 | |||||||
Highway stations | 127 | 127 | 127 | 126 | 124 | |||||||
Outside Italy | 1,625 | 1,586 | 1,604 | 1,624 | 1,628 | |||||||
Germany | 455 | 454 | 445 | 460 | 469 | |||||||
France | 188 | 181 | 173 | 169 | 160 | |||||||
Austria/Switzerland | 582 | 547 | 575 | 585 | 591 | |||||||
Eastern Europe | 400 | 404 | 411 | 410 | 408 | |||||||
Service stations selling Blu products | 4,994 | 5,179 | 5,226 | 5,021 | 5,749 | |||||||
"Multi-Energy" service stations | 5 | 5 | 6 | 6 | 6 | |||||||
Service stations selling LPG and natural gas | 657 | 864 | 1,031 | 1,024 | 1,206 | |||||||
Non-oil sales | (euro million) | 137 | 156 | 159 | 151 | 151 |
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Eni Fact Book Refining & Marketing
Average throughput |
(kliters/No. of service stations) | 2010 |
2011 |
2012 |
2013 |
2014 |
Italy | 2,322 | 2,173 | 1,976 | 1,657 | 1,534 | |||||
Germany | 3,360 | 3,237 | 3,226 | 3,279 | 3,299 | |||||
France | 2,310 | 2,209 | 2,121 | 2,194 | 2,139 | |||||
Austria/Switzerland | 1,711 | 1,645 | 1,879 | 1,890 | 1,891 | |||||
Eastern Europe | 2,508 | 2,591 | 2,145 | 2,044 | 1,979 | |||||
Average throughput | 2,352 | 2,206 | 2,064 | 1,828 | 1,725 |
Market shares in Italy |
(%) | 2010 |
2011 |
2012 |
2013 |
2014 |
Retail | 30.4 | 30.5 | 31.2 | 27.5 | 25.5 | |||||
Gasoline | 27.9 | 27.8 | 28.8 | 24.8 | 22.3 | |||||
Gasoil | 32.5 | 32.6 | 33.2 | 29.6 | 27.9 | |||||
LPG (automotive) | 21.4 | 22.7 | 23.1 | 20.8 | 20.0 | |||||
Lubricants | 35.7 | 27.7 | 35.4 | 30.4 | 25.8 | |||||
Wholesale | 29.2 | 28.6 | 29.5 | 28.8 | 26.7 | |||||
Gasoil | 33.5 | 30.8 | 33.0 | 32.7 | 27.3 | |||||
Fuel oil | 17.8 | 25.5 | 23.3 | 17.5 | 21.8 | |||||
Bunker | 40.4 | 33.6 | 37.6 | 39.4 | 39.1 | |||||
Lubricants | 24.0 | 23.6 | 24.1 | 23.5 | 23.4 | |||||
Domestic market share (retail and wholesale) | 29.8 | 29.3 | 30.3 | 28.3 | 26.3 |
Retail market shares outside Italy |
(%) | 2010 |
2011 |
2012 |
2013 |
2014 |
Central Europe | ||||||||||
Austria | 7.0 | 9.6 | 11.7 | 11.9 | 12.1 | |||||
Switzerland | 6.5 | 6.6 | 7.1 | 7.3 | 7.3 | |||||
Germany | 3.4 | 3.1 | 3.2 | 3.2 | 3.2 | |||||
France | 1.1 | 1.0 | 0.9 | 0.9 | 0.8 | |||||
Eastern Europe | ||||||||||
Hungary | 11.9 | 11.9 | 11.9 | 11.7 | 11.9 | |||||
Czech Republic | 11.8 | 11.6 | 10.8 | 9.8 | 8.9 | |||||
Slovakia | 9.7 | 9.8 | 9.7 | 9.7 | 9.5 | |||||
Slovenia | 2.3 | 2.2 | 2.2 | 2.3 | 2.4 | |||||
Romania | 1.5 | 1.7 | 1.8 | 1.9 | 1.8 |
Capital expenditure |
(euro million) | 2010 |
2011 |
2012 |
2013 |
2014 |
Italy | 633 | 803 | 834 | 598 | 466 | |||||
Outside Italy | 78 | 63 | 64 | 74 | 71 | |||||
711 | 866 | 898 | 672 | 537 | ||||||
Refining, supply and logistic | 446 | 629 | 675 | 497 | 362 | |||||
Italy | 444 | 626 | 671 | 491 | 357 | |||||
Outside Italy | 2 | 3 | 4 | 6 | 5 | |||||
Marketing | 246 | 228 | 223 | 175 | 175 | |||||
Italy | 170 | 168 | 163 | 107 | 109 | |||||
Outside Italy | 76 | 60 | 60 | 68 | 66 | |||||
Other | 19 | 9 | ||||||||
711 | 866 | 898 | 672 | 537 |
- 55 -
Eni Fact Book Versalis
Versalis |
Key performance indicators |
2010 |
2011 |
2012 |
2013 |
2014 |
||||||||
Injury frequency rate of total Eni workforce | (No. of accidents per million of worked hours) | 3.42 | 2.74 | 1.09 | 0.57 | 0.28 | |||||||||||
Net sales from operations (a) | (euro million) | 6,141 | 6,491 | 6,418 | 5,859 | 5,284 | |||||||||||
Intermediates | 2,833 | 2,987 | 3,050 | 2,709 | 2,310 | ||||||||||||
Polymers | 3,126 | 3,299 | 3,188 | 2,933 | 2,800 | ||||||||||||
Other sales | 182 | 205 | 180 | 217 | 174 | ||||||||||||
Operating profit | (86 | ) | (424 | ) | (681 | ) | (725 | ) | (704 | ) | |||||||
Adjusted operating profit | (96 | ) | (273 | ) | (483 | ) | (386 | ) | (346 | ) | |||||||
Adjusted net profit | (73 | ) | (206 | ) | (395 | ) | (338 | ) | (277 | ) | |||||||
Capital expenditure | 251 | 216 | 172 | 314 | 282 | ||||||||||||
Production | (ktonnes) | 7,220 | 6,245 | 6,090 | 5,817 | 5,283 | |||||||||||
Sales of petrochemical products | 4,731 | 4,040 | 3,953 | 3,785 | 3,463 | ||||||||||||
Average plant utilization rate | (%) | 72.9 | 65.3 | 66.7 | 65.3 | 71.3 | |||||||||||
Employees at year end | (number) | 5,972 | 5,804 | 5,668 | 5,708 | 5,443 | |||||||||||
Direct GHG emissions | (mmtonnes CO2 eq) | 4.71 | 4.15 | 3.72 | 3.69 | 3.09 | |||||||||||
NMVOC (Non-Methane Volatile Organic Compound) emissions | (ktonnes) | 4.71 | 4.18 | 4.40 | 3.93 | 3.51 | |||||||||||
NOx emissions (nitrogen oxide) | (ktonnes NO2 eq) | 4.87 | 4.14 | 3.43 | 3.29 | 2.45 | |||||||||||
Recycled/reused freshwater | (%) | 82.7 | 81.9 | 81.6 | 86.2 | 87.7 | |||||||||||
(a) Before elimination of intragroup sales. |
Performance of the year
I In 2014, the injury frequency rate
(employees and contractors) was more than halved (down by
50.9%) compared to 2013, continuing the positive trend
registered in the last years. I In 2014, greenhouse gas emissions and other emissions in the atmosphere were lower than in 2013 (down by 16.3%), following the substantial restructuring of the production assets of Versalis through the closure of the Hythe site, as well as the shutdown of the petrochemical site of Porto Marghera for almost all 2014. Recycled/reused freshwater rate improved, up to 87.7%. I In 2014, adjusted net loss was euro 277 million, euro 61 million lower than in 2013, benefiting from the improvement of margins in intermediates and polyethylene reported in the last part of the year. This was achieved against the backdrop of continued weakness in commodity demand and increasing competition from non-EU producers. Results reflected efficiency initiatives and restructuring programs, mainly relating to the start-up of the Porto Torres green chemical project and the shutdown of certain unprofitable production units. |
I Sales of petrochemical products amounted
to 3,463 ktonnes, down by 322 ktonnes, or 8.5% from 2013,
driven by decrease in consumption. I In 2014, the expenditure in R&D amounted to approximately euro 40 million. 14 patent applications were filed. Restructuring
of petrochemical activities in Sardinia |
- 56 -
Eni Fact Book Versalis
At the end of December 2014,
Versalis signed an agreement to divest the Sarroch plant
to the refining company Saras, which owns a refinery
close to Enis petrochemical site. The agreement
includes the disposal of the Versalis plants connected
with the production cycle of the refinery, in particular
the reforming unit, the propylene splitter unit and other
related services, including the logistics system. Porto Marghera Green Chemical project |
applications such as
detergents, bio-lubricants and chemicals for the oil
industry. Development and
sustainability initiatives |
Strategy | ||
Versalis was negatively affected by a steep decline in market demand and increasing competitive pressure, mainly in commodity business with lower technological content. In this scenario, the priority is the economic sustainability of Versalis in the medium and long term. The breakeven for adjusted operating profit and operating cash flow is expected to be achieved starting from 2016, performing and completing the following strategic guidelines: (i) critical sites reconversions (in particular Porto Torres, Priolo, Porto Marghera, Sarroch and Hythe) with the shutdown and/or divestment of no more competitive production and consolidation of the other businesses; (ii) refocusing on high value-added productions (i.e. specialties) also through the development of green chemistry; and (iii) empowerment of productive platform by means of the internationalization of the business to serve consumers even more global and markets feature by high growth of demand rate, also through strategic alliances signed with industrial players. |
The materials
produced by Versalis are obtained following a
manufacturing cycle which involves several processing
stages. Virgin naphtha, a raw material which is a
distillation product from petroleum, undergoes thermal
cracking also known as steam-cracking. The component molecules split into simpler molecules: monomers (ethylene, propylene, butadiene, etc.) and into blends of aromatic compounds. The monomers are then reconstituted into more complex molecules: polymers. The following are produced from polymers: polyethylene, styrenes and elastomers used by processing companies to produce a whole variety of products for everyday use. The blends of aromatic compounds, properly treated, are used to produce intermediates, so-called because they are used in the manufacturing of products for everyday use. |
- 57 -
Eni Fact Book Versalis
Eni through Versalis
performs activities of production and marketing of
petrochemical products (basic petrochemicals and
polymers), leveraging on a wide range of proprietary
technologies, advanced production facilities, as well as
a large and efficient retail network present in 17
European countries. Versalis portfolio of patents
and proprietary technologies covers the whole field of
basic petrochemicals and polymers: phenol and its
derivatives, polyethylene, styrenes and elastomers, as
well as catalysts and special chemical products. |
that allowed it to achieve
excellence in all technologies in the specific business
areas in order to compete in markets worldwide. A key
role is played by the most innovative proprietary
catalysts, particularly those based on zeolites developed
by Versalis as building blocks of some of its most
advanced technologies and available worldwide. The principal objective of basic petrochemicals is granting the adequate availability of monomers (ethylene, butadiene and benzene) covering the needs of further production processes: in particular olefins production is strictly linked with the polyethylene and elastomers business, aromatics grant the benzene availability necessary to produce intermediate products used in the production of resins, artificial fibers and polystyrene. In polymers business Versalis is one of the most relevant European producers of elastomers, where it is present in almost all the relevant sectors (in particular, in the automotive industry), polystyrene and polyethylene, whose most relevant use is in flexible packaging. |
Business areas Intermediates |
the shutdown of Porto
Marghera plant from February until the end of the year,
as well as lower productions in Sarroch plant. In
addition, derivatives productions decreased by 10% due to
disruptions and maintenance standstills registered in the
second part of the year. Polymers |
- 58 -
Eni Fact Book Versalis
in this sector and produces
a wide range of products for the following sectors:
tyres, footwear, adhesives, building components, pipes,
electrical cables, car components and sealing, household
appliances; they can be used as modifiers for plastics
and bitumens, as additives for lubricating oils (solid
elastomers); carpet backing, paper coating, molded foams
(synthetic latex). Versalis is one of the world's major
producers of elastomers and synthetic latex. Polymers
revenues (euro 2,800 million) decreased by euro 133
million, or by 4.5% from 2013 due to average unit prices
and volumes of elastomers decreasing by 8% and 5%,
respectively, driven by continuing weakness of automotive
sectored demand and low price of Asian producers. These
negatives were further exacerbated by the decrease of
average styrenics prices (down by 4%) and sold volumes
down by 4%, also due to new import flows coming from
North Africa. Polyethylene prices were barely unchanged. |
down by 11% and BR down by
3%), nitrilic (down by 9%) and lattices (down by 19%).
Lower sales of styrenes (down by 4%) is attributable to
lower volumes sold of compact polystyrene (down by 4%),
due to demand weakness, monomer styrol (down by 15%) due
to lower production availability in Europe following the
planned shutdown. The sold volumes of polyethylene
reported an increase due to higher sales of HDPE (up by
7%), Eva (up by 9%) and LLDPE (up by 1%) driven by lower
supply in Europe. LDPE sales decreased by 2.5%. Polymers production (2,311 ktonnes) decreased by 1.9% from 2013, mainly in elastomers segment (down by 8%), due to the definitive closing of Hythe with lower production of lattices and SBR rubbers, and of BR rubbers due to declining demand. Styrene productions decreased by 4% with lower volumes of styrol (down by 5%) due to the planned shutdown of the second half of 2014 and compact polystyrene (down by 6%), partly offset by higher productions of ABS/San (up by 11%) for short-term production rescheduling. Polyethylene sales increased by 2%, due to higher production at Brindisi site (HDPE up by 5%) due to the planned standstill of olefin production lines, and Eva in the Oberhausen site (up by 53%). |
Product availability |
(ktonnes) | 2010 |
2011 |
2012 |
2013 |
2014 |
Intermediates | 4,860 | 4,101 | 3,595 | 3,462 | 2,972 | ||||||||||
Polymers | 2,360 | 2,144 | 2,495 | 2,355 | 2,311 | ||||||||||
Production | 7,220 | 6,245 | 6,090 | 5,817 | 5,283 | ||||||||||
Consumption and losses | (2,912 | ) | (2,631 | ) | (2,545 | ) | (2,394 | ) | (2,292 | ) | |||||
Purchases and change in inventories | 423 | 426 | 408 | 362 | 472 | ||||||||||
4,731 | 4,040 | 3,953 | 3,785 | 3,463 |
Revenues by geographic area |
(euro million) | 2010 |
2011 |
2012 |
2013 |
2014 |
Italy | 3,131 | 3,364 | 3,172 | 2,758 | 2,565 | |||||
Rest of Europe | 2,632 | 2,747 | 2,826 | 2,704 | 2,433 | |||||
Asia | 139 | 182 | 271 | 238 | 157 | |||||
Americas | 127 | 101 | 84 | 126 | 105 | |||||
Africa | 108 | 93 | 61 | 28 | 10 | |||||
Other areas | 4 | 4 | 4 | 5 | 14 | |||||
6,141 | 6,491 | 6,418 | 5,859 | 5,284 |
Revenues by product |
(euro million) | 2010 |
2011 |
2012 |
2013 |
2014 |
Olefins | 1,705 | 1,754 | 1,792 | 1,487 | 1,305 | |||||
Aromatics | 704 | 835 | 819 | 791 | 610 | |||||
Intermediates | 375 | 359 | 440 | 431 | 394 | |||||
Elastomers | 834 | 1,062 | 979 | 716 | 627 | |||||
Styrenics | 744 | 780 | 774 | 800 | 745 | |||||
Polyethylene | 1,597 | 1,496 | 1,434 | 1,418 | 1,428 | |||||
Other | 182 | 205 | 180 | 216 | 174 | |||||
6,141 | 6,491 | 6,418 | 5,859 | 5,284 |
Capital expenditure |
(euro million) | 2010 |
2011 |
2012 |
2013 |
2014 |
251 | 216 | 172 | 314 | 282 | ||||||
of which: | ||||||||||
- upkeeping | 59 | 59 | 25 | 66 | 26 | |||||
- plant upgrades | 116 | 53 | 53 | 170 | 161 | |||||
- HSE | 29 | 46 | 38 | 52 | 30 | |||||
- energy recovery | 45 | 42 | 41 | 8 | 28 |
- 59 -
Eni Fact Book Engineering & Construction
Engineering & Construction |
Key performance indicators |
2010 |
2011 |
2012 |
2013 |
2014 |
||||||||
Injury frequency rate of total Eni workforce | (No. of accidents per million of worked hours) | 0.40 | 0.31 | 0.32 | 0.26 | 0.28 | |||||||
Net sales from operations (a) | (euro million) | 10,581 | 11,834 | 12,799 | 11,598 | 12,873 | |||||||
Operating profit | 1,302 | 1,422 | 1,453 | (98 | ) | 18 | |||||||
Adjusted operating profit | 1,326 | 1,443 | 1,485 | (99 | ) | 479 | |||||||
Adjusted net profit | 994 | 1,098 | 1,111 | (253 | ) | 309 | |||||||
Capital expenditure | 1,552 | 1,090 | 1,011 | 902 | 694 | ||||||||
Orders acquired | (euro million) | 12,935 | 12,505 | 13,391 | 10,062 | 17,971 | |||||||
Order backlog | 20,505 | 20,417 | 19,739 | 17,065 | 22,147 | ||||||||
Employees at year end | (number) | 38,826 | 38,561 | 43,387 | 47,209 | 49,559 | |||||||
Employees outside Italy rate | (%) | 87.3 | 86.5 | 88.1 | 89.1 | 89.9 | |||||||
Local managers rate | 45.3 | 43.0 | 41.3 | 41.3 | 42.0 | ||||||||
Local procurement rate | 61.3 | 56.4 | 57.4 | 54.3 | 55.6 | ||||||||
Direct GHG emissions | (mmtonnes CO2 eq) | 1.11 | 1.32 | 1.54 | 1.54 | 1.42 | |||||||
Water withdrawals | (million of cubic meters) | 6.56 | 7.24 | 8.25 | 8.74 | 6.32 | |||||||
(a) Before elimination of intragroup sales. |
Performance of the year |
I In 2014, the injury frequency rate
registered a 7.7% increase due to a higher index for
contractors (up by 12.7%), partially offset by a lower
injury frequency rate for employees (down by 4.9%). I In 2014, adjusted net profit of the Engineering & Construction segment amounted to euro 309 million; up by euro 562 million from the adjusted net loss of euro 253 million reported in 2013 which reflected extraordinary losses of margin of certain projects. I Orders acquired amounted to euro 17,971 million (euro 10,062 million in 2013), 97% of which relating to the works outside Italy, while orders from Eni companies amounted to 8% of the total. |
I Order backlog amounted to euro 22,147
million at December 31, 2014 (euro 17,065 million at
December 31, 2013), of which euro 9,035 million to be
fulfilled in 2015. I In 2014, R&D expenditure amounted approximately to euro 12 million. 20 patent applications were filed. I Capital expenditure amounted to euro 694 million (euro 902 million in 2013), mainly regarded the upgrading of the drilling and construction fleet. |
Strategy | ||
For the Engineering & Construction segment, the 2014 was characterized by the return to profitability, the reduction of net debt and significant results in terms of new orders. The company has a large and diversified order backlog which will express its competitive advantage as that in: ultra deepwater projects, laying of trunk line in extreme conditions, large and complex onshore projects. |
Engineering & Construction
Offshore Saipem is well positioned in the market of large projects for the development of offshore hydrocarbon fields leveraging on its technical and operational skills (supported by a technologically advanced fleet |
and the ability to operate in complex environments) and engineering and project management capabilities acquired on the marketplace over recent years (such as Bouygues Offshore). Saipem intends to consolidate its market share strengthening its EPIC oriented business model and leveraging on its satisfactory long-term relationships with |
- 60 -
Eni Fact Book Engineering & Construction
the Major oil companies and
National Oil Companies. Higher levels of efficiency and
flexibility are expected to be achieved by reaching the
technological excellence and the highest economies of
scale in its engineering hubs employing local resources
in contexts where this represents a competitive
advantage, integrating in its own business model the
direct management of construction process through the
creation of a large construction yard in South-East Asia
and revamping/upgrading its construction fleet. Over the
next years, Saipem will invest in the upgrading of its
fleet, by building a large fabrication yard in Brazil and
buying other supporting assets for drilling activity. In 2014, revenues amounted to euro 7,202 million, up by 40% from 2013 due to higher levels of activity in South Central America, Australia and West Africa. Orders acquired in the year amounted to euro 10,043 million (euro 5,581 million in 2013), mainly related to: (i) an EPCI contract on behalf of Total concerning conversion of the two FPSO units, with an oil capacity of 115,000 bbl/d and a storage capacity of 1.7 mmboe. The two converted FPSO units will be utilized to support the development of Kaombo field, located in Block 32 offshore Angola; (ii) a transportation and installation contract on behalf of BP for the Phase 2 of the Shah Deniz field development, offshore Azerbaijan; and (iii) an EPCI contract on behalf of Pemex, in Mexico, for the development of the Lakach field. The scope of work of the contract involves the engineering, procurement, construction and installation of the system connecting the offshore field with the onshore gas conditioning plant. In 2014, Saipem continued the development of technologies, leveraging on the realization of innovative solutions developed in previous years, particularly in the SURF (Subsea Umbilical Risers and Flowlines) and the area of the pipelines, as well as part of the technologies applied on materials and cross functional issues. In the field of the laying of pipelines in very deep waters, various technologies have been applied in the relevant commercial projects, such as the Anti-Flooding Tool that prevents the flooding of the pipe during the laying phase and M1 technology to coating the joints. Engineering & Construction Onshore In the Engineering & Construction Onshore
business, Saipem is one of the largest operators on
turnkey contract base at a worldwide level in the
oil&gas segment. Saipem operates in the construction
of plants for hydrocarbon production (extraction,
separation, stabilization, collection of hydrocarbons,
water injection) and hydrocarbon treatment (removal and
recovery of sulphur dioxide and carbon dioxide,
fractioning of gaseous liquids, recovery of condensates)
and in the installation of large onshore transport
systems (pipelines, compression stations, terminals).
Saipem preserves its own competitiveness through its
technology excellence granted by its engineering hubs,
its distinctive know-how in the construction of projects
in the high-tech market of LNG and the management of
large parts of engineering activities in cost efficient
areas. In the medium term, underpinning upward trends in
the oil service market, Saipem will be focused on taking
advantage of the opportunities arising from the market in
the plant and pipeline segments leveraging on its solid
competitive position in the realization of complex
projects in the strategic areas of Middle East, Caspian
Sea, Northern and Western Africa and Russia. |
acquired were: (i) contracts
on behalf of Saudi Aramco relating to the Integrated
Gasification Combined Cycle project (Jazan) as a part of
the activities related to the construction of the largest
power plant in the world to be located near the namesake
city of Jizan. Furthermore, Saudi Aramco awarded to
Saipem an EPC contract for the Loops 4 & 5 of the
Shedgum-Yanbu Gas Pipeline; (ii) a contract on behalf of
Saudi Aramco relating to the expansion of the onshore
production centers at the Khurais, Mazajili and Abu Jifan
fields in Saudi Arabia. The construction of new
facilities will allow to process additional 500,000
barrels per day from the above mentioned fields; and
(iii) a contract in the Caspian Region regarding
engineering, fabrication and pre-commissioning
activities, as well as the load-out of pipe racks. In onshore business, the research and development activity involved technology on proprietary process and new solutions in order to improve the quality profile of the project proposals to customers, mainly with regard to energy efficiency and environmental impact, in particular, relating to development process, continued improvements in performance and environmental compatibility of proprietary technology Snamprogetti UreaTM have been registered. Moreover, in the field of energy efficiency, studies on the production of hydroelectric power in petrochemical plants or for the production of fertilizers have been successfully completed. |
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Eni Fact Book Engineering & Construction
Offshore drilling Saipem
is the only engineering and construction contractor that
provides both offshore and onshore drilling services to
oil companies. In the offshore drilling segment, Saipem
mainly operates in West Africa, the North Sea, the
Mediterranean Sea and the Middle East and boasts
significant market positions in the most complex segments
of deep and ultra-deep offshore, leveraging on the
outstanding technical features of its drilling platforms
and vessels, capable of drilling exploration and
development wells at a maximum water depth of 9,200
meters. In parallel, investments are ongoing to renew and
to keep up the production capacity of other fleet
equipment (upgrade equipment to the characteristics of
projects or to clients needs and purchase of
support equipment). |
7, for operations in Saudi
Arabia; and (iii) a two-year extension of the contract on
behalf of NDC (National Drilling Co) for the lease of the
jack-up Perro Negro 2 for operations in the Persian Gulf
starting in January 2015. During the year the company
prosecuted in the development of new techniques and rigs
for drilling activities in frontier areas such as Artic
Sea. Onshore drilling Saipem operates in this segment as contractor for the
major international and national oil companies executing
its activity mainly in South America, Saudi Arabia, North
Africa and, at a lower extent, in Europe. |
- 62 -
Eni Fact Book Engineering & Construction
- 63 -
Eni Fact Book Engineering & Construction
Main operating data |
2010 |
2011 |
2012 |
2013 |
2014 |
Offshore pipelines laid | (km) | 1,365 | 1,682 | 1,435 | 1,106 | 1,772 | ||||||
Onshore pipelines laid | (km) | 385 | 889 | 543 | 433 | 1,897 | ||||||
Offshore structures installed | (t) | 46,606 | 105,033 | 122,765 | 206,959 | 101,799 | ||||||
Onshore structures installed | (t) | 874,428 | 353,480 | 261,410 | 178,252 | 90,873 | ||||||
Offshore drilling | (km) | 130 | 178 | 194 | 201 | 188 | ||||||
Onshore drilling | (km) | 881 | 985 | 953 | 821 | 878 | ||||||
Offshore wells drilled | (units) | 44 | 64 | 104 | 127 | 123 | ||||||
Onshore wells drilled | (units) | 279 | 307 | 373 | 373 | 427 |
Drilling vessels |
Name | Type | Drilling plant | Maximum depth (m) |
Drilling maximum (m) |
Other | |||||
Perro Negro 2 | Jack-up | Oilwell E 2000 | 90 | 6,500 | Heliport provided | |||||
Perro Negro 3 | Jack-up | Ideco E 2100 | 90 | 6,000 | Heliport provided | |||||
Perro Negro 5 | Jack-up | National 1320 UE | 90 | 6,500 | Heliport provided | |||||
Perro Negro 6 | Jack-up | National SSDG 3000 | 107 | 9,150 | Heliport provided | |||||
Perro Negro 7 | Jack-up | National 1625 UE | 115 | 9,150 | Heliport provided | |||||
Perro Negro 8 | Jack-up | NOV SSDG 3000 | 107 | 9,100 | Heliport provided | |||||
Scarabeo 3 | Semi-submersible drilling platform helped propulsion system | National 1625 DE | 550 | 7,600 | Heliport provided | |||||
Scarabeo 4 | Semi-submersible drilling platform helped propulsion system | National 1625 DE | 550 | 7,600 | Heliport provided | |||||
Scarabeo 5 | Semi-submersible drilling platform helped propulsion system | Emco C 3 | 1,900 | 8,000 | Heliport provided | |||||
Scarabeo 6 | Semi-submersible drilling platform helped propulsion system | Oilwell E 3000 | 500 | 7,600 | Heliport provided | |||||
Scarabeo 7 | Semi-submersible drilling platform helped propulsion system | Wirth GH 3000 EG | 1,500 | 8,000 | Heliport provided | |||||
Scarabeo 8 | Semi-submersible drilling platform helped propulsion system | NOV AHD-500-4600 | 3,000 | 10,660 | Heliport provided | |||||
Scarabeo 9 | Semi-submersible drilling platform helped propulsion system | Aker Maritime Ram Rig | 3,650 | 15,200 | Heliport provided | |||||
Saipem 10000 | Ultra deep waters drillship, self-propelled, dynamic positioning | Wirth GH 4500 EG | 3,000 | 9,200 | Oil storage capacity: 140,000 bbl; heliport provided | |||||
Saipem 12000 | Ultra deep waters drillship, self-propelled, dynamic positioning | NOV SSDG 5750 | 3,650 | 10,000 | Heliport provided | |||||
Saipem TAD | Tender assisted drilling barge | Bentec 1500 Hp | 150 | 4,877 | Heliport provided |
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Eni Fact Book Engineering & Construction
Construction vessels |
Name | Type | Laying technique | Transport/lifting capability (t) | Maximum laying depth (m) | Pipelaying maximum diameter (inches) | |||||
Saipem 7000 | Semi-submersible, self-propelled pipelay and DP vessel capable of lifting structures and J-laying pipelines in deep waters | J | 14,000 | 3,000 | 32 | |||||
Saipem FDS | Multipurpose monohull dynamically positioned crane and pipelay (J-lay) vessel utilized for the development of hydrocarbon fields in deep waters | J | 600 | over 2,000 | 22 | |||||
Saipem FDS 2 | Multipurpose monohull dynamically positioned crane and pipelay (J-lay) vessel utilized for the development of hydrocarbon fields in deep waters. The vessel is equipped with a J-lay tower | J, S | 2,000 | 3,000 | 36 | |||||
Castoro 6 | Semi-submersible pipelay vessel capable of laying large diameter pipe | S | 300 | 1,000 | 60 | |||||
Castoro 7 | Semi-submersible pipelay vessel capable of laying large diameter pipe | S | 1,000 | 60 | ||||||
Castoro 8 | Crane and pipelay vessel | S | 2,200 | 600 | 60 | |||||
Castorone | Self-propelled, dynamically positioned pipe-laying vessel operating in S-lay mode with a 120-meter long S-lay stern ramp composed of 3 articulated and adjustable stinger sections for shallow and deep-water operation, a holding capacity of up to 750 tonnes (expandable to 1,000 tonnes), pipelay capability of up to 60 inches, onboard fabrication facilities for triple and double joints and large pipe storage capacity in cargo holds | S | 1,000 | 60 | ||||||
Saipem 3000 | Mono-hull, self-propelled DP crane ship, capable of laying flexible pipes and umbilicals in deep waters and lifting structures | 2,200 | ||||||||
Bar Protector | Dynamically positioned dive support vessel used for deep waters diving operations and works on platforms | |||||||||
Semac 1 | Semi-submersible pipelay vessel capable of laying pipes in deep waters | S | 318 | 600 | 58 | |||||
Castoro 2 | Derrick/lay barge | S | 1,000 | 60 | ||||||
Castoro 10 | Trench/lay barge | S | 300 | 60 | ||||||
Castoro 12 | Shallow waters pipelay barge | S | 1.4 | 40 | ||||||
S355 | Derrick/lay barge | S | 600 | 42 | ||||||
Castoro 16 | Post-trenching and back-filling barge of pipelines operating in ultra-shallow waters | 1.4 | 40 | |||||||
Saibos 230 | Derrick pipelay barge equipped with a mobile crane for piling, marine terminals and fixed platforms | S | 30 | |||||||
Ersai 1 (a) | Technical pontoon equipped with two crawler cranes, capable of carrying out installations whilst grounded on the seabed (1,800 tonnes + 300 tonnes) | 2,100 | ||||||||
Ersai 2 (a) | Work barge equipped with a fixed crane capable of lifting structures | 200 | ||||||||
Ersai 3 (a) | Self-propelled workshop/storage barge used as support vessel, with storage space and office space for 50 people | |||||||||
Ersai 4 (a) | Self-propelled workshop/storage barge used as support vessel, with storage space and office space for 150 people | |||||||||
Ersai 400 (a) | Accommodation barge for up to 400 people, equipped with antigas shelter for H2S leaks | |||||||||
Castoro 9 | Launching/cargo barge | 5,000 | ||||||||
Castoro 11 | Heavy duty cargo barge | 15,000 | ||||||||
Castoro 14 | Deck cargo barge | 10,000 | ||||||||
Castoro 15 | Deck cargo barge | 6,200 | ||||||||
S42 | Deck cargo barge, for S7000 tower storage | 8,000 | ||||||||
S43 | Deck cargo barge | |||||||||
S44 | Launching/cargo barge | 30,000 | ||||||||
S45 | Launching/cargo barge | 20,000 | ||||||||
S46 | Deck cargo barge | |||||||||
S47 | Deck cargo barge | |||||||||
S600 | Deck cargo barge | 30,000 | ||||||||
FPSO - Cidade de Vitoria | FPSO unit with a production capacity of up to 100,000 barrels a day | |||||||||
FPSO - Gimboa | FPSO unit with a production capacity of up to 60,000 barrels a day |
(a) Owned by the Saipem-managed joint venture ER SAI Caspian Contractor Llc. |
- 65 -
Eni Fact Book Financial Data
Financial Data
Profit and loss account |
(euro million) | 2010 |
2011 |
2012 |
2013 |
2014 |
Net sales from operations | 96,617 | 107,690 | 127,109 | 114,697 | 109,847 | ||||||||||
Other income and revenues | 967 | 926 | 1,548 | 1,387 | 1,101 | ||||||||||
Total revenues | 97,584 | 108,616 | 128,657 | 116,084 | 110,948 | ||||||||||
Purchases, services and other | (68,774 | ) | (78,795 | ) | (95,034 | ) | (90,003 | ) | (86,340 | ) | |||||
Payroll and related costs | (4,428 | ) | (4,404 | ) | (4,640 | ) | (5,301 | ) | (5,337 | ) | |||||
Total operating expenses | (73,202 | ) | (83,199 | ) | (99,674 | ) | (95,304 | ) | (91,677 | ) | |||||
Other operating income (expense) | 131 | 171 | (158 | ) | (71 | ) | 145 | ||||||||
Depreciation, depletion, amortization and impairments | (9,031 | ) | (8,785 | ) | (13,617 | ) | (11,821 | ) | (11,499 | ) | |||||
Operating profit | 15,482 | 16,803 | 15,208 | 8,888 | 7,917 | ||||||||||
Finance income (expense) | (749 | ) | (1,146 | ) | (1,371 | ) | (1,009 | ) | (1,065 | ) | |||||
Net income from investments | 1,112 | 2,123 | 2,789 | 6,085 | 490 | ||||||||||
Profit before income taxes | 15,845 | 17,780 | 16,626 | 13,964 | 7,342 | ||||||||||
Income taxes | (8,581 | ) | (9,903 | ) | (11,679 | ) | (9,005 | ) | (6,492 | ) | |||||
Tax rate (%) | 54.2 | 55.7 | 70.2 | 64.5 | 88.4 | ||||||||||
Net profit - continuing operations | 7,264 | 7,877 | 4,947 | 4,959 | 850 | ||||||||||
Attributable to: | |||||||||||||||
- Enis shareholders | 6,252 | 6,902 | 4,200 | 5,160 | 1,291 | ||||||||||
- non-controlling interest | 1,012 | 975 | 747 | (201 | ) | (441 | ) | ||||||||
Net profit - discontinued operations | 119 | (74 | ) | 3,732 | |||||||||||
Attributable to: | |||||||||||||||
- Enis shareholders | 66 | (42 | ) | 3,590 | |||||||||||
- non-controlling interest | 53 | (32 | ) | 142 | |||||||||||
Net profit | 7,383 | 7,803 | 8,679 | 4,959 | 850 | ||||||||||
Attributable to: | |||||||||||||||
- Enis shareholders | 6,318 | 6,860 | 7,790 | 5,160 | 1,291 | ||||||||||
- non-controlling interest | 1,065 | 943 | 889 | (201 | ) | (441 | ) | ||||||||
Net profit attributable to Eni's shareholders - continuing operations | 6,252 | 6,902 | 4,200 | 5,160 | 1,291 | ||||||||||
Exclusion of inventory holding (gains) losses | (610 | ) | (724 | ) | (23 | ) | 438 | 1,008 | |||||||
Exclusion of special items | 1,128 | 760 | 2,953 | (1,168 | ) | 1,408 | |||||||||
of which: | |||||||||||||||
- non-recurring items | (246 | ) | 69 | ||||||||||||
- other special items | 1,374 | 691 | 2,953 | (1,168 | ) | 1,408 | |||||||||
Adjusted net profit attributable to Enis shareholders - continuing operations | 6,770 | 6,938 | 7,130 | 4,430 | 3,707 | ||||||||||
Adjusted net profit attributable to Enis shareholders - discontinued operations | 99 | 31 | 195 | ||||||||||||
Adjusted net profit attributable to Enis shareholders | 6,869 | 6,969 | 7,325 | 4,430 | 3,707 |
- 66 -
Eni Fact Book Financial Data
Summarized Group Balance Sheet |
(euro million) | Dec. 31, 2010 |
Dec. 31, 2011 |
Dec. 31, 2012 |
Dec. 31, 2013 |
Dec. 31, 2014 |
Fixed assets | |||||||||||||||
Property, plant and equipment | 67,404 | 73,578 | 64,798 | 63,763 | 71,962 | ||||||||||
Inventories - Compulsory stock | 2,024 | 2,433 | 2,541 | 2,573 | 1,581 | ||||||||||
Intangible assets | 11,172 | 10,950 | 4,487 | 3,876 | 3,645 | ||||||||||
Equity-accounted investments and other investments | 6,090 | 6,242 | 8,538 | 6,180 | 5,130 | ||||||||||
Receivables and securities held for operating purposes | 1,743 | 1,740 | 1,126 | 1,339 | 1,861 | ||||||||||
Net payables related to capital expenditure | (970 | ) | (1,576 | ) | (1,139 | ) | (1,255 | ) | (1,971 | ) | |||||
87,463 | 93,367 | 80,351 | 76,476 | 82,208 | |||||||||||
Net working capital | |||||||||||||||
Inventories | 6,589 | 7,575 | 8,578 | 7,939 | 7,555 | ||||||||||
Trade receivables | 17,221 | 17,709 | 19,958 | 21,212 | 19,709 | ||||||||||
Trade payables | (13,111 | ) | (13,436 | ) | (15,052 | ) | (15,584 | ) | (15,015 | ) | |||||
Tax payables and provisions for net deferred tax liabilities | (2,684 | ) | (3,503 | ) | (3,265 | ) | (3,062 | ) | (1,865 | ) | |||||
Provisions | (11,792 | ) | (12,735 | ) | (13,567 | ) | (13,120 | ) | (15,898 | ) | |||||
Other current assets and liabilities | (1,286 | ) | 281 | 1,735 | 1,274 | 222 | |||||||||
(5,063 | ) | (4,109 | ) | (1,613 | ) | (1,341 | ) | (5,292 | ) | ||||||
Provisions for employee post-retirement benefits | (1,032 | ) | (1,039 | ) | (1,407 | ) | (1,279 | ) | (1,313 | ) | |||||
Assets held for sale including related liabilities | 479 | 206 | 155 | 2,156 | 291 | ||||||||||
CAPITAL EMPLOYED, NET | 81,847 | 88,425 | 77,486 | 76,012 | 75,894 | ||||||||||
Shareholders equity | |||||||||||||||
attributable to: - Eni's shareholders | 51,206 | 55,472 | 59,060 | 58,210 | 59,754 | ||||||||||
attributable to: - non-controlling interest | 4,522 | 4,921 | 3,357 | 2,839 | 2,455 | ||||||||||
55,728 | 60,393 | 62,417 | 61,049 | 62,209 | |||||||||||
Net borrowings | 26,119 | 28,032 | 15,069 | 14,963 | 13,685 | ||||||||||
TOTAL LIABILITIES AND SHAREHOLDERS EQUITY | 81,847 | 88,425 | 77,486 | 76,012 | 75,894 |
- 67 -
Eni Fact Book Financial Data
Summarized Group Cash Flow Statement |
(euro million) | 2010 |
2011 |
2012 |
2013 |
2014 |
Net profit - continuing operations | 7,264 | 7,877 | 4,947 | 4,959 | 850 | ||||||||||
Adjustments to reconcile net profit to net cash provided by operating activities: | |||||||||||||||
- depreciation, depletion and amortization and other non-monetary items | 8,521 | 8,606 | 11,501 | 9,723 | 12,131 | ||||||||||
- net gains on disposal of assets | (558 | ) | (1,176 | ) | (875 | ) | (3,770 | ) | (95 | ) | |||||
- dividends, interests, taxes and other changes | 8,829 | 9,918 | 11,962 | 9,174 | 6,655 | ||||||||||
Changes in working capital related to operations | (1,158 | ) | (1,696 | ) | (3,281 | ) | 456 | 2,668 | |||||||
Dividends received, taxes paid, interest (paid) received during the period | (8,758 | ) | (9,766 | ) | (11,702 | ) | (9,516 | ) | (7,099 | ) | |||||
Net cash provided by operating activities - continuing operations | 14,140 | 13,763 | 12,552 | 11,026 | 15,110 | ||||||||||
Net cash provided by operating activities - discontinued operations | 554 | 619 | 15 | ||||||||||||
Net cash provided by operating activities | 14,694 | 14,382 | 12,567 | 11,026 | 15,110 | ||||||||||
Capital expenditure - continuing operations | (12,450 | ) | (11,909 | ) | (12,805 | ) | (12,800 | ) | (12,240 | ) | |||||
Capital expenditure - discontinued operations | (1,420 | ) | (1,529 | ) | (756 | ) | |||||||||
Capital expenditure | (13,870 | ) | (13,438 | ) | (13,561 | ) | (12,800 | ) | (12,240 | ) | |||||
Investments and purchase of consolidated subsidiaries and businesses | (410 | ) | (360 | ) | (569 | ) | (317 | ) | (408 | ) | |||||
Disposals | 1,113 | 1,912 | 6,025 | 6,360 | 3,684 | ||||||||||
Other cash flow related to capital expenditure, investments and disposals | 228 | 627 | (193 | ) | (243 | ) | 435 | ||||||||
Free cash flow | 1,755 | 3,123 | 4,269 | 4,026 | 6,581 | ||||||||||
Borrowings (repayment) of debt related to financing activities | (26 | ) | 41 | (79 | ) | (3,981 | ) | (414 | ) | ||||||
Changes in short and long-term financial debt | 2,272 | 1,104 | 5,814 | 1,715 | (628 | ) | |||||||||
Dividends paid and changes in non-controlling interests and reserves | (4,099 | ) | (4,327 | ) | (3,743 | ) | (4,225 | ) | (4,434 | ) | |||||
Effect of changes in consolidation and exchange differences | 39 | 10 | (16 | ) | (40 | ) | 78 | ||||||||
NET CASH FLOW FOR THE PERIOD | (59 | ) | (49 | ) | 6,245 | (2,505 | ) | 1,183 |
Change in net borrowings |
(euro million) | 2010 |
2011 |
2012 |
2013 |
2014 |
Free cash flow | 1,755 | 3,123 | 4,269 | 4,026 | 6,581 | ||||||||||
Net borrowings of acquired companies | (33 | ) | (2 | ) | (21 | ) | (19 | ) | |||||||
Net borrowings of divested companies | (192 | ) | 12,446 | (23 | ) | ||||||||||
Exchange differences on net borrowings and other changes | (687 | ) | (517 | ) | (345 | ) | 349 | (850 | ) | ||||||
Dividends paid and changes in non-controlling interest and reserves | (4,099 | ) | (4,327 | ) | (3,743 | ) | (4,225 | ) | (4,434 | ) | |||||
CHANGE IN NET BORROWINGS | (3,064 | ) | (1,913 | ) | 12,625 | 106 | 1,278 |
Net sales from operations |
(euro million) | 2010 |
2011 |
2012 |
2013 |
2014 |
Exploration & Production | 29,497 | 29,121 | 35,874 | 31,264 | 28,488 | ||||||||||
Gas & Power | 27,806 | 33,093 | 36,198 | 32,212 | 28,250 | ||||||||||
Refining & Marketing | 43,190 | 51,219 | 62,531 | 57,238 | 56,153 | ||||||||||
Versalis | 6,141 | 6,491 | 6,418 | 5,859 | 5,284 | ||||||||||
Engineering & Construction | 10,581 | 11,834 | 12,799 | 11,598 | 12,873 | ||||||||||
Other activities | 105 | 85 | 119 | 80 | 78 | ||||||||||
Corporate and financial companies | 1,386 | 1,365 | 1,369 | 1,453 | 1,378 | ||||||||||
Impact of unrealized intragroup profit elimination (a) | 100 | (54 | ) | (75 | ) | 18 | 54 | ||||||||
Consolidation adjustment | (22,189 | ) | (25,464 | ) | (28,124 | ) | (25,025 | ) | (22,711 | ) | |||||
96,617 | 107,690 | 127,109 | 114,697 | 109,847 |
(a) This item concerned mainly intragroup sales of commodities, services and capital goods recorded in the assets of the purchasing business segment as of end of the period. |
Net sales to customers |
(euro million) | 2010 |
2011 |
2012 |
2013 |
2014 |
Exploration & Production | 12,947 | 10,677 | 15,552 | 13,046 | 11,870 | ||||||||||
Gas & Power | 26,837 | 31,749 | 34,160 | 30,987 | 27,147 | ||||||||||
Refining & Marketing | 41,845 | 48,428 | 59,569 | 54,341 | 53,957 | ||||||||||
Versalis | 5,898 | 6,202 | 6,007 | 5,570 | 5,031 | ||||||||||
Engineering & Construction | 8,779 | 10,510 | 11,690 | 10,580 | 11,629 | ||||||||||
Other activities | 80 | 62 | 79 | 41 | 31 | ||||||||||
Corporate and financial companies | 131 | 116 | 127 | 114 | 128 | ||||||||||
Impact of unrealized intragroup profit elimination | 100 | (54 | ) | (75 | ) | 18 | 54 | ||||||||
96,617 | 107,690 | 127,109 | 114,697 | 109,847 |
- 68 -
Eni Fact Book Financial Data
Net sales by geographic area of destination |
(euro million) | 2010 |
2011 |
2012 |
2013 |
2014 |
Italy | 45,896 | 31,906 | 33,860 | 31,949 | 29,621 | ||||||
Other EU countries | 21,125 | 35,920 | 35,909 | 31,629 | 29,933 | ||||||
Rest of Europe | 4,172 | 7,153 | 9,645 | 11,462 | 12,434 | ||||||
Africa | 13,068 | 11,333 | 14,710 | 12,073 | 11,640 | ||||||
Americas | 6,282 | 9,612 | 15,244 | 7,752 | 8,944 | ||||||
Asia | 5,785 | 10,258 | 16,394 | 18,608 | 16,257 | ||||||
Other areas | 289 | 1,508 | 1,347 | 1,224 | 1,018 | ||||||
Total outside Italy | 50,721 | 75,784 | 93,249 | 82,748 | 80,226 | ||||||
96,617 | 107,690 | 127,109 | 114,697 | 109,847 |
Net sales by geographic area of origin |
(euro million) | 2010 |
2011 |
2012 |
2013 |
2014 |
Italy | 55,455 | 62,789 | 72,607 | 73,483 | 69,847 | ||||||
Other EU countries | 16,983 | 20,914 | 19,570 | 15,626 | 15,936 | ||||||
Rest of Europe | 1,986 | 3,101 | 3,736 | 3,292 | 3,264 | ||||||
Africa | 12,586 | 9,384 | 13,976 | 11,851 | 11,174 | ||||||
Americas | 5,588 | 7,107 | 12,020 | 5,793 | 5,838 | ||||||
Asia | 3,692 | 3,937 | 4,458 | 3,779 | 3,362 | ||||||
Other areas | 327 | 458 | 742 | 873 | 426 | ||||||
Total outside Italy | 41,162 | 44,901 | 54,502 | 41,214 | 40,000 | ||||||
96,617 | 107,690 | 127,109 | 114,697 | 109,847 |
Purchases, services and other |
(euro million) | 2010 |
2011 |
2012 |
2013 |
2014 |
Production costs - raw, ancillary and consumable materials and goods | 48,407 | 60,826 | 74,643 | 67,004 | 63,605 | ||||||||||
Production costs - services | 14,939 | 13,551 | 15,142 | 17,711 | 16,979 | ||||||||||
Operating leases and other | 2,997 | 3,045 | 3,440 | 3,678 | 4,080 | ||||||||||
Net provisions | 1,401 | 527 | 856 | 850 | 494 | ||||||||||
Other expenses | 1,252 | 1,140 | 1,358 | 1,147 | 1,516 | ||||||||||
less: | |||||||||||||||
capitalized direct costs associated with self-constructed tangible and intangible assets | (222 | ) | (294 | ) | (405 | ) | (387 | ) | (334 | ) | |||||
68,774 | 78,795 | 95,034 | 90,003 | 86,340 |
Principal accountant fees and services |
(euro thousand) | 2010 |
2011 |
2012 |
2013 |
2014 |
Audit fees | 21,114 | 22,031 | 23,042 | 28,023 | 27,607 | ||||||
Audit-related fees | 183 | 1,113 | 1,351 | 1,574 | 1,287 | ||||||
Tax fees | 166 | 323 | 25 | 21 | 11 | ||||||
All other fees | 3 | ||||||||||
21,463 | 23,467 | 24,421 | 29,618 | 28,905 |
Payroll and related costs |
(euro million) | 2010 |
2011 |
2012 |
2013 |
2014 |
Wages and salaries | 3,299 | 3,435 | 3,904 | 4,395 | 4,645 | ||||||||||
Social security contributions | 631 | 675 | 679 | 657 | 709 | ||||||||||
Cost related to defined benefit plans | 154 | 148 | 110 | 92 | 104 | ||||||||||
Other costs | 557 | 334 | 184 | 411 | 235 | ||||||||||
less: | |||||||||||||||
capitalized direct costs associated with self-constructed tangible and intangible assets | (213 | ) | (188 | ) | (237 | ) | (254 | ) | (356 | ) | |||||
4,428 | 4,404 | 4,640 | 5,301 | 5,337 |
- 69 -
Eni Fact Book Financial Data
Depreciation, depletion, amortization and impairments |
(euro million) | 2010 |
2011 |
2012 |
2013 |
2014 |
Exploration & Production | 6,928 | 6,251 | 7,985 | 7,810 | 8,473 | ||||||||||
Gas & Power | 425 | 413 | 480 | 413 | 334 | ||||||||||
Refining & Marketing | 333 | 351 | 366 | 345 | 283 | ||||||||||
Versalis | 83 | 90 | 90 | 95 | 99 | ||||||||||
Engineering & Construction | 513 | 596 | 683 | 721 | 737 | ||||||||||
Other activities | 2 | 2 | 1 | 1 | 1 | ||||||||||
Corporate and financial companies | 79 | 75 | 65 | 61 | 69 | ||||||||||
Impact of unrealized intragroup profit elimination | (20 | ) | (23 | ) | (25 | ) | (25 | ) | (26 | ) | |||||
Total depreciation, depletion and amortization | 8,343 | 7,755 | 9,645 | 9,421 | 9,970 | ||||||||||
Exploration & Production | 123 | 189 | 547 | 19 | 690 | ||||||||||
Gas & Power | 426 | 154 | 2,443 | 1,685 | 25 | ||||||||||
Refining & Marketing | 76 | 488 | 843 | 633 | 284 | ||||||||||
Versalis | 52 | 160 | 112 | 44 | 96 | ||||||||||
Engineering & Construction | 3 | 35 | 25 | 420 | |||||||||||
Other activities | 8 | 4 | 2 | 19 | 14 | ||||||||||
Total impairment | 688 | 1,030 | 3,972 | 2,400 | 1,529 | ||||||||||
9,031 | 8,785 | 13,617 | 11,821 | 11,499 |
Operating profit by segment |
(euro million) | 2010 |
2011 |
2012 |
2013 |
2014 |
Exploration & Production | 13,866 | 15,887 | 18,470 | 14,868 | 10,766 | ||||||||||
Gas & Power | 896 | (326 | ) | (3,125 | ) | (2,967 | ) | 186 | |||||||
Refining & Marketing | 149 | (273 | ) | (1,264 | ) | (1,492 | ) | (2,229 | ) | ||||||
Versalis | (86 | ) | (424 | ) | (681 | ) | (725 | ) | (704 | ) | |||||
Engineering & Construction | 1,302 | 1,422 | 1,453 | (98 | ) | 18 | |||||||||
Other activities | (1,384 | ) | (427 | ) | (300 | ) | (337 | ) | (272 | ) | |||||
Corporate and financial companies | (361 | ) | (319 | ) | (341 | ) | (399 | ) | (246 | ) | |||||
Impact of unrealized intragroup profit elimination | 1,100 | 1,263 | 996 | 38 | 398 | ||||||||||
15,482 | 16,803 | 15,208 | 8,888 | 7,917 |
- 70 -
Eni Fact Book Financial Data
Non-GAAP measures
Reconciliation of reported operating profit and reported net profit to results on an adjusted basis
Management evaluates Group
and business performance on the basis of adjusted
operating profit and adjusted net profit, which are
arrived at by excluding inventory holding gains or
losses, special items and, in determining the business
segments adjusted results, finance charges on
finance debt and interest income. The adjusted operating
profit of each business segment reports gains and losses
on derivative financial instruments entered into to
manage exposure to movements in foreign currency exchange
rates which impact industrial margins and translation of
commercial payables and receivables. Accordingly also
currency translation effects recorded through profit and
loss are reported within business segments adjusted
operating profit. The taxation effect of the items
excluded from adjusted operating or net profit is
determined based on the specific rate of taxes applicable
to each of them (27.5%). The Italian statutory tax rate
is applied to finance charges and income. Adjusted
operating profit and adjusted net profit are non-GAAP
financial measures under either IFRS, or US GAAP.
Management includes them in order to facilitate a
comparison of base business performance across periods,
and to allow financial analysts to evaluate Enis
trading performance on the basis of their forecasting
models. The following is a description of items that
are excluded from the calculation of adjusted results. Special items include certain significant income or charges pertaining to either: (i) infrequent or unusual events and transactions, being identified as non-recurring items under such circumstances; (ii) certain events or transactions which are not considered to be representative of the ordinary course of business, as in the case of environmental provisions, restructuring charges, asset impairments or write ups and gains or losses on divestments even though they occurred in past periods or are likely to occur in |
future ones; or (iii)
exchange rate differences and derivatives relating to
industrial activities and commercial payables and
receivables, particularly exchange rate derivatives to
manage commodity pricing formulas which are quoted in a
currency other than the functional currency. Those items
are reclassified in operating profit with a corresponding
adjustment to net finance charges, notwithstanding the
handling of foreign currency exchange risks is made
centrally by netting off naturally occurring opposite
positions and then dealing with any residual risk
exposure in the exchange rate market. As provided for in Decision No. 15519 of July 27, 2006 of the Italian market regulator (CONSOB), non-recurring material income or charges are to be clearly reported in the managements discussion and financial tables. Also, special items allow to allocate to future reporting periods gains and losses on re-measurement at fair value of certain non hedging commodity derivatives and exchange rate derivatives relating to commercial exposures, lacking the criteria to be designed as hedges, including the ineffective portion of cash flow hedges and certain derivative financial instruments embedded in the pricing formula of long-term gas supply agreements of the Exploration & Production segment. Finance
charges or income related to net borrowings excluded
from the adjusted net profit of business segments are
comprised of interest charges on finance debt and
interest income earned on cash and cash equivalents not
related to operations. For a reconciliation of adjusted operating profit, adjusted net profit to reported operating profit and reported net profit see tables below. |
- 71 -
Eni Fact Book Financial Data
2010 | (euro million) |
Other
activities (a) |
Discontinued
operations |
||||
Exploration
& Production |
Gas
& Power (a) |
Refining
& Marketing |
Versalis |
Engineering
& Construction |
Corporate
and financial companies |
Snam |
Other
activities |
Impact
of unrealized intragroup profit elimination |
GROUP |
Snam |
Consolidation
adjustments |
Total |
Continuing operations |
|||||||||||||||
Reported operating profit | 13,866 | 896 | 149 | (86 | ) | 1,302 | (361 | ) | 2,000 | (1,384 | ) | (271 | ) | 16,111 | (2,000 | ) | 1,371 | (629 | ) | 15,482 | ||||||||||||||||||||||
Exclusion of inventory holding (gains) losses | (117 | ) | (659 | ) | (105 | ) | (881 | ) | (881 | ) | ||||||||||||||||||||||||||||||||
Exclusion of special items: | ||||||||||||||||||||||||||||||||||||||||||
net asset impairments | 127 | 426 | 76 | 52 | 3 | 10 | 8 | 702 | (10 | ) | (10 | ) | 692 | |||||||||||||||||||||||||||||
gains on disposal of assets | (241 | ) | (16 | ) | 5 | 4 | (248 | ) | (4 | ) | (4 | ) | (252 | ) | ||||||||||||||||||||||||||||
risk provisions | 78 | 2 | 8 | 7 | 95 | 95 | ||||||||||||||||||||||||||||||||||||
environmental charges | 30 | 16 | 169 | 9 | 1,145 | 1,369 | (9 | ) | (9 | ) | 1,360 | |||||||||||||||||||||||||||||||
provision for redundancy incentives | 97 | 52 | 113 | 26 | 14 | 88 | 23 | 10 | 423 | (23 | ) | (23 | ) | 400 | ||||||||||||||||||||||||||||
commodity derivatives | 30 | (10 | ) | (22 | ) | (2 | ) | (2 | ) | |||||||||||||||||||||||||||||||||
exchange rate differences and derivatives | 14 | 195 | (10 | ) | 17 | 216 | 216 | |||||||||||||||||||||||||||||||||||
other | 5 | (38 | ) | 5 | 9 | (19 | ) | (19 | ) | |||||||||||||||||||||||||||||||||
Special items of operating profit | 32 | 489 | 329 | 95 | 24 | 96 | 46 | 1,179 | 2,290 | (46 | ) | (46 | ) | 2,244 | ||||||||||||||||||||||||||||
Adjusted operating profit | 13,898 | 1,268 | (181 | ) | (96 | ) | 1,326 | (265 | ) | 2,046 | (205 | ) | (271 | ) | 17,520 | (2,046 | ) | 1,371 | (675 | ) | 16,845 | |||||||||||||||||||||
Net finance (expense) income (b) | (205 | ) | 34 | 33 | (783 | ) | 22 | (9 | ) | (908 | ) | (22 | ) | (22 | ) | (930 | ) | |||||||||||||||||||||||||
Net income (expense) from investments (b) | 274 | 362 | 92 | 1 | 10 | 44 | (2 | ) | 781 | (44 | ) | (44 | ) | 737 | ||||||||||||||||||||||||||||
Income taxes (b) | (8,358 | ) | (397 | ) | 33 | 22 | (375 | ) | 181 | (667 | ) | 102 | (9,459 | ) | 667 | (78 | ) | 589 | (8,870 | ) | ||||||||||||||||||||||
Tax rate (%) | 59.8 | 23.9 | .. | 27.4 | 31.6 | 54.4 | 53.3 | |||||||||||||||||||||||||||||||||||
Adjusted net profit | 5,609 | 1,267 | (56 | ) | (73 | ) | 994 | (867 | ) | 1,445 | (216 | ) | (169 | ) | 7,934 | (1,445 | ) | 1,293 | (152 | ) | 7,782 | |||||||||||||||||||||
of which attributable to: | ||||||||||||||||||||||||||||||||||||||||||
- non-controlling interest | 1,065 | (53 | ) | 1,012 | ||||||||||||||||||||||||||||||||||||||
- Enis shareholders | 6,869 | (99 | ) | 6,770 | ||||||||||||||||||||||||||||||||||||||
Reported net profit attributable to Enis shareholders | 6,318 | (66 | ) | 6,252 | ||||||||||||||||||||||||||||||||||||||
Exclusion of inventory holding(gains) losses | (610 | ) | (610 | ) | ||||||||||||||||||||||||||||||||||||||
Exclusion of special items: | 1,161 | (33 | ) | 1,128 | ||||||||||||||||||||||||||||||||||||||
- non-recurring charges | (246 | ) | (246 | ) | ||||||||||||||||||||||||||||||||||||||
- other special (income) charges | 1,407 | (33 | ) | 1,374 | ||||||||||||||||||||||||||||||||||||||
Adjusted net profit attributable to Enis shareholders | 6,869 | (99 | ) | 6,770 |
(a) Following the announced divestment plan, Snam results are reclassified from "Gas & Power" sector to "Other activities" and accounted as discontinued operations. (b) Excluding special items. |
- 72 -
Eni Fact Book Financial Data
2011 | (euro million) |
Other
activities (a) |
Discontinued
operations |
||||
Exploration
& Production |
Gas
& Power (a) |
Refining
& Marketing |
Versalis |
Engineering
& Construction |
Corporate
and financial companies |
Snam |
Other
activities |
Impact
of unrealized intragroup profit elimination |
GROUP |
Snam |
Consolidation
adjustments |
Total |
Continuing operations |
|||||||||||||||
Reported operating profit | 15,887 | (326 | ) | (273 | ) | (424 | ) | 1,422 | (319 | ) | 2,084 | (427 | ) | (189 | ) | 17,435 | (2,084 | ) | 1,452 | (632 | ) | 16,803 | ||||||||||||||||||||
Exclusion of inventory holding (gains) losses | (166 | ) | (907 | ) | (40 | ) | (1,113 | ) | (1,113 | ) | ||||||||||||||||||||||||||||||||
Exclusion of special items: | ||||||||||||||||||||||||||||||||||||||||||
net asset impairments | 190 | 154 | 488 | 160 | 35 | (9 | ) | 4 | 1,022 | 9 | 9 | 1,031 | ||||||||||||||||||||||||||||||
gains on disposal of assets | (63 | ) | 10 | 4 | (1 | ) | (4 | ) | (7 | ) | (61 | ) | 4 | 4 | (57 | ) | ||||||||||||||||||||||||||
risk provisions | 77 | 8 | (6 | ) | 9 | 88 | 88 | |||||||||||||||||||||||||||||||||||
environmental charges | 34 | 1 | 10 | 141 | 186 | (10 | ) | (10 | ) | 176 | ||||||||||||||||||||||||||||||||
provision for redundancy incentives | 44 | 34 | 81 | 17 | 10 | 9 | 6 | 8 | 209 | (6 | ) | (6 | ) | 203 | ||||||||||||||||||||||||||||
commodity derivatives | 1 | 45 | (3 | ) | (28 | ) | 15 | 15 | ||||||||||||||||||||||||||||||||||
exchange rate differences and derivatives | (2 | ) | (82 | ) | (4 | ) | 3 | (85 | ) | (85 | ) | |||||||||||||||||||||||||||||||
other | 18 | 17 | 27 | 51 | 24 | (13 | ) | 124 | (24 | ) | (24 | ) | 100 | |||||||||||||||||||||||||||||
Special items of operating profit | 188 | 245 | 641 | 191 | 21 | 53 | 27 | 201 | 1,567 | (27 | ) | (27 | ) | 1,540 | ||||||||||||||||||||||||||||
Adjusted operating profit | 16,075 | (247 | ) | (539 | ) | (273 | ) | 1,443 | (266 | ) | 2,111 | (226 | ) | (189 | ) | 17,889 | (2,111 | ) | 1,452 | (659 | ) | 17,230 | ||||||||||||||||||||
Net finance (expense) income (b) | (231 | ) | 43 | (876 | ) | 19 | 5 | (1,040 | ) | (19 | ) | (19 | ) | (1,059 | ) | |||||||||||||||||||||||||||
Net income (expense) from investments (b) | 624 | 363 | 99 | 95 | 1 | 44 | (3 | ) | 1,223 | (44 | ) | (44 | ) | 1,179 | ||||||||||||||||||||||||||||
Income taxes (b) | (9,603 | ) | 93 | 176 | 67 | (440 | ) | 388 | (918 | ) | (1 | ) | 78 | (10,160 | ) | 918 | (195 | ) | 723 | (9,437 | ) | |||||||||||||||||||||
Tax rate (%) | 58.3 | .. | .. | 28.6 | 42.2 | 56.2 | 5.4 | |||||||||||||||||||||||||||||||||||
Adjusted net profit | 6,865 | 252 | (264 | ) | (206 | ) | 1,098 | (753 | ) | 1,256 | (225 | ) | (111 | ) | 7,912 | (1,256 | ) | 1,257 | 1 | 7,913 | ||||||||||||||||||||||
of which attributable to: | ||||||||||||||||||||||||||||||||||||||||||
- non-controlling interest | 943 | 32 | 975 | |||||||||||||||||||||||||||||||||||||||
- Enis shareholders | 6,969 | (31 | ) | 6,938 | ||||||||||||||||||||||||||||||||||||||
Reported net profit attributable to Enis shareholders | 6,860 | 42 | 6,902 | |||||||||||||||||||||||||||||||||||||||
Exclusion of inventory holding (gains) losses | (724 | ) | (724 | ) | ||||||||||||||||||||||||||||||||||||||
Exclusion of special items: | 833 | (73 | ) | 760 | ||||||||||||||||||||||||||||||||||||||
- non-recurring charges | 69 | 69 | ||||||||||||||||||||||||||||||||||||||||
- other special (income) charges | 764 | (73 | ) | 691 | ||||||||||||||||||||||||||||||||||||||
Adjusted net profit attributable to Enis shareholders | 6,969 | (31 | ) | 6,938 |
(a) Following the announced divestment plan, Snam results are reclassified from "Gas & Power" sector to "Other activities" and accounted as discontinued operations. (b) Excluding special items. |
- 73 -
Eni Fact Book Financial Data
2012 | (euro million) |
Other
activities (a) |
Discontinued
operations |
||||
Exploration
& Production |
Gas
& Power (a) |
Refining
& Marketing |
Versalis |
Engineering
& Construction |
Corporate
and financial companies |
Snam |
Other
activities |
Impact
of unrealized intragroup profit elimination |
GROUP |
Snam |
Consolidation
adjustments |
Total |
Continuing operations |
|||||||||||||||
Reported operating profit | 18,470 | (3,125 | ) | (1,264 | ) | (681 | ) | 1,453 | (341 | ) | 1,679 | (300 | ) | 208 | 16,099 | (1,679 | ) | 788 | (891 | ) | 15,208 | |||||||||||||||||||||
Exclusion of inventory holding (gains) losses | 163 | (29 | ) | 63 | (214 | ) | (17 | ) | (17 | ) | ||||||||||||||||||||||||||||||||
Exclusion of special items: | ||||||||||||||||||||||||||||||||||||||||||
asset impairments | 550 | 2,443 | 846 | 112 | 25 | 2 | 3,978 | 3,978 | ||||||||||||||||||||||||||||||||||
gains on disposal of assets | (542 | ) | (3 | ) | 5 | 1 | 3 | (22 | ) | (12 | ) | (570 | ) | 22 | 22 | (548 | ) | |||||||||||||||||||||||||
risk provisions | 7 | 831 | 49 | 18 | 5 | 35 | 945 | 945 | ||||||||||||||||||||||||||||||||||
environmental charges | (2 | ) | 40 | 71 | 25 | 134 | (71 | ) | (71 | ) | 63 | |||||||||||||||||||||||||||||||
provision for redundancy incentives | 6 | 5 | 19 | 14 | 7 | 11 | 2 | 2 | 66 | (2 | ) | (2 | ) | 64 | ||||||||||||||||||||||||||||
commodity derivatives | 1 | 1 | (3 | ) | (1 | ) | (1 | ) | ||||||||||||||||||||||||||||||||||
exchange rate differences and derivatives | (9 | ) | (52 | ) | (8 | ) | (11 | ) | (80 | ) | (80 | ) | ||||||||||||||||||||||||||||||
other | 54 | 138 | 53 | 26 | 271 | 271 | ||||||||||||||||||||||||||||||||||||
Special items of operating profit | 67 | 3,360 | 1,004 | 135 | 32 | 16 | 51 | 78 | 4,743 | (51 | ) | (51 | ) | 4,692 | ||||||||||||||||||||||||||||
Adjusted operating profit | 18,537 | 398 | (289 | ) | (483 | ) | 1,485 | (325 | ) | 1,730 | (222 | ) | (6 | ) | 20,825 | (1,730 | ) | 788 | (942 | ) | 19,883 | |||||||||||||||||||||
Net finance (expense) income (b) | (264 | ) | 11 | (14 | ) | (3 | ) | (7 | ) | (867 | ) | (54 | ) | (24 | ) | (1,222 | ) | 54 | 54 | (1,168 | ) | |||||||||||||||||||||
Net income (expense) from investments (b) | 436 | 233 | 43 | 2 | 46 | 99 | 38 | (1 | ) | 896 | (38 | ) | (38 | ) | 858 | |||||||||||||||||||||||||||
Income taxes (b) | (11,283 | ) | (163 | ) | 79 | 89 | (413 | ) | 116 | (712 | ) | 2 | (12,285 | ) | 712 | (123 | ) | 589 | (11,696 | ) | ||||||||||||||||||||||
Tax rate (%) | 60.3 | 25.4 | .. | 27.1 | 41.5 | 59.9 | 59.8 | |||||||||||||||||||||||||||||||||||
Adjusted net profit | 7,426 | 479 | (181 | ) | (395 | ) | 1,111 | (977 | ) | 1,002 | (247 | ) | (4 | ) | 8,214 | (1,002 | ) | 665 | (337 | ) | 7,877 | |||||||||||||||||||||
of which attributable to: | ||||||||||||||||||||||||||||||||||||||||||
- non-controlling interest | 889 | (142 | ) | 747 | ||||||||||||||||||||||||||||||||||||||
- Enis shareholders | 7,325 | (195 | ) | 7,130 | ||||||||||||||||||||||||||||||||||||||
Reported net profit attributable to Enis shareholders | 7,790 | (3,590 | ) | 4,200 | ||||||||||||||||||||||||||||||||||||||
Exclusion of inventory holding (gains) losses | (23 | ) | (23 | ) | ||||||||||||||||||||||||||||||||||||||
Exclusion of special items | (442 | ) | 3,395 | 2,953 | ||||||||||||||||||||||||||||||||||||||
Adjusted net profit attributable to Enis shareholders | 7,325 | (195 | ) | 7,130 |
(a) Following the announced divestment plan, Snam results are reclassified from "Gas & Power" sector to "Other activities" and accounted as discontinued operations. (b) Excluding special items. |
- 74 -
Eni Fact Book Financial Data
2013 | (euro million) |
Exploration
& Production |
Gas
& Power |
Refining
& Marketing |
Versalis |
Engineering
& Construction |
Other
activities |
Corporate
and financial companies |
|
GROUP |
||||||||||
Reported operating profit | 14,868 | (2,967 | ) | (1,492 | ) | (725 | ) | (98 | ) | (337 | ) | (399 | ) | 38 | 8,888 | ||||||||||||
Exclusion of inventory holding (gains) losses | 191 | 221 | 213 | 91 | 716 | ||||||||||||||||||||||
Exclusion of special items: | |||||||||||||||||||||||||||
asset impairments | 19 | 1,685 | 633 | 44 | 19 | 2,400 | |||||||||||||||||||||
gains on disposal of assets | (283 | ) | 1 | (9 | ) | 107 | (3 | ) | (187 | ) | |||||||||||||||||
risk provisions | 7 | 292 | 4 | 31 | 334 | ||||||||||||||||||||||
environmental charges | (1 | ) | 93 | 61 | 52 | 205 | |||||||||||||||||||||
provision for redundancy incentives | 52 | 10 | 91 | 23 | 2 | 20 | 72 | 270 | |||||||||||||||||||
commodity derivatives | (2 | ) | 314 | 5 | (1 | ) | (1 | ) | 315 | ||||||||||||||||||
exchange rate differences and derivatives | (2 | ) | (186 | ) | (2 | ) | (5 | ) | (195 | ) | |||||||||||||||||
other | (16 | ) | 23 | 3 | (109 | ) | 8 | (5 | ) | (96 | ) | ||||||||||||||||
Special items of operating profit | (225 | ) | 2,138 | 814 | 126 | (1 | ) | 127 | 67 | 3,046 | |||||||||||||||||
Adjusted operating profit | 14,643 | (638 | ) | (457 | ) | (386 | ) | (99 | ) | (210 | ) | (332 | ) | 129 | 12,650 | ||||||||||||
Net finance (expense) income (a) | (264 | ) | 14 | (6 | ) | (2 | ) | (5 | ) | 4 | (571 | ) | (830 | ) | |||||||||||||
Net income (expense) from investments (a) | 367 | 70 | 56 | 2 | 1 | 290 | 786 | ||||||||||||||||||||
Income taxes (a) | (8,796 | ) | 301 | 175 | 50 | (151 | ) | 129 | (90 | ) | (8,382 | ) | |||||||||||||||
Tax rate (%) | 59.7 | .. | .. | .. | 41.5 | 66.5 | |||||||||||||||||||||
Adjusted net profit | 5,950 | (253 | ) | (232 | ) | (338 | ) | (253 | ) | (205 | ) | (484 | ) | 39 | 4,224 | ||||||||||||
of which attributable to: | |||||||||||||||||||||||||||
- non-controlling interest | (206 | ) | |||||||||||||||||||||||||
- Enis shareholders | 4,430 | ||||||||||||||||||||||||||
Reported net profit attributable to Enis shareholders | 5,160 | ||||||||||||||||||||||||||
Exclusion of inventory holding (gains) losses | 438 | ||||||||||||||||||||||||||
Exclusion of special items | (1,168 | ) | |||||||||||||||||||||||||
Adjusted net profit attributable to Enis shareholders | 4,430 |
(a) Excluding special items. |
- 75 -
Eni Fact Book Financial Data
2014 | (euro million) |
Exploration
& Production |
Gas
& Power |
Refining
& Marketing |
Versalis |
Engineering
& Construction |
Other
activities |
Corporate
and financial companies |
|
GROUP |
||||||||||
Reported operating profit | 10,766 | 186 | (2,229 | ) | (704 | ) | 18 | (272 | ) | (246 | ) | 398 | 7,917 | ||||||||||||||
Exclusion of inventory holding (gains) losses | (119 | ) | 1,576 | 170 | (167 | ) | 1,460 | ||||||||||||||||||||
Exclusion of special items: | |||||||||||||||||||||||||||
asset impairments | 692 | 25 | 284 | 96 | 420 | 14 | 1,531 | ||||||||||||||||||||
gains on disposal of assets | (76 | ) | (2 | ) | 45 | 2 | 3 | (28 | ) | ||||||||||||||||||
risk provisions | (5 | ) | (42 | ) | 25 | 7 | 5 | (10 | ) | ||||||||||||||||||
environmental charges | 111 | 27 | 41 | 179 | |||||||||||||||||||||||
provision for redundancy incentives | 24 | 11 | (6 | ) | 5 | (3 | ) | (22 | ) | 9 | |||||||||||||||||
commodity derivatives | (28 | ) | (43 | ) | 42 | 4 | 9 | (16 | ) | ||||||||||||||||||
exchange rate differences and derivatives | 6 | 228 | (9 | ) | 4 | 229 | |||||||||||||||||||||
other | 172 | 64 | 25 | 12 | 32 | (2 | ) | 303 | |||||||||||||||||||
Special items of operating profit | 785 | 243 | 445 | 188 | 461 | 94 | (19 | ) | 2,197 | ||||||||||||||||||
Adjusted operating profit | 11,551 | 310 | (208 | ) | (346 | ) | 479 | (178 | ) | (265 | ) | 231 | 11,574 | ||||||||||||||
Net finance (expense) income (a) | (287 | ) | 7 | (9 | ) | (3 | ) | (6 | ) | (22 | ) | (542 | ) | (862 | ) | ||||||||||||
Net income (expense) from investments (a) | 323 | 49 | 67 | (3 | ) | 21 | (156 | ) | 301 | ||||||||||||||||||
Income taxes (a) | (7,164 | ) | (176 | ) | 3 | 75 | (185 | ) | 312 | (79 | ) | (7,214 | ) | ||||||||||||||
Tax rate (%) | 61.8 | 48.1 | .. | 37.4 | 65.5 | ||||||||||||||||||||||
Adjusted net profit | 4,423 | 190 | (147 | ) | (277 | ) | 309 | (200 | ) | (651 | ) | 152 | 3,799 | ||||||||||||||
of which attributable to: | |||||||||||||||||||||||||||
- non-controlling interest | 92 | ||||||||||||||||||||||||||
- Enis shareholders | 3,707 | ||||||||||||||||||||||||||
Reported net profit attributable to Enis shareholders | 1,291 | ||||||||||||||||||||||||||
Exclusion of inventory holding (gains) losses | 1,008 | ||||||||||||||||||||||||||
Exclusion of special items | 1,408 | ||||||||||||||||||||||||||
Adjusted net profit attributable to Enis shareholders | 3,707 |
(a) Excluding special items. |
- 76 -
Eni Fact Book Financial Data
Breakdown of special items (a) |
(euro million) | 2010 |
2011 |
2012 |
2013 |
2014 |
Non-recurring charges (income) | (246 | ) | 69 | ||||||||||||
of which: estimated charge from the possible resolution of the TSKJ matter | |||||||||||||||
of which: settlement/payments on antitrust and other Authorities proceedings | (246 | ) | 69 | ||||||||||||
Other special charges (income): | 2,536 | 1,498 | 4,743 | 3,046 | 2,197 | ||||||||||
- asset impairments | 702 | 1,022 | 3,978 | 2,400 | 1,531 | ||||||||||
- gains on disposal of assets | (248 | ) | (61 | ) | (570 | ) | (187 | ) | (28 | ) | |||||
- risk provisions | 95 | 88 | 945 | 334 | (10 | ) | |||||||||
- environmental charges | 1,369 | 186 | 134 | 205 | 179 | ||||||||||
- provision for redundancy incentives | 423 | 209 | 66 | 270 | 9 | ||||||||||
- commodity derivatives | (2 | ) | 15 | (1 | ) | 315 | (16 | ) | |||||||
- exchange rate differences and derivatives | 216 | (85 | ) | (80 | ) | (195 | ) | 229 | |||||||
- other | (19 | ) | 124 | 271 | (96 | ) | 303 | ||||||||
Special items of operating profit | 2,290 | 1,567 | 4,743 | 3,046 | 2,197 | ||||||||||
Net finance (income) expense | (181 | ) | 89 | 203 | 179 | 203 | |||||||||
of which: | |||||||||||||||
exchange rate differences and derivatives | (216 | ) | 85 | 80 | 195 | (229 | ) | ||||||||
Net income (expense) from investments | (324 | ) | (883 | ) | (5,373 | ) | (5,299 | ) | (189 | ) | |||||
of which: | |||||||||||||||
gains on disposals of assets | (332 | ) | (1,118 | ) | (2,354 | ) | (3,599 | ) | (159 | ) | |||||
of which: international transport | (1,044 | ) | |||||||||||||
of which: divestment of the 28.57% of Enis interest in Eni East Africa | (3,359 | ) | |||||||||||||
of which: Galp | (311 | ) | (98 | ) | |||||||||||
of which: Snam | (2,019 | ) | (75 | ) | |||||||||||
of which: Padana Energia | (169 | ) | |||||||||||||
of which: GreenStream | (93 | ) | |||||||||||||
gains on investment revaluation | (3,151 | ) | (1,682 | ) | (54 | ) | |||||||||
of which: Galp | (1,700 | ) | |||||||||||||
of which: Snam | (1,451 | ) | |||||||||||||
of which: Artic Russia | (1,682 | ) | |||||||||||||
impairments | 28 | 191 | 191 | 11 | (38 | ) | |||||||||
Income taxes | (624 | ) | 60 | (15 | ) | 901 | (270 | ) | |||||||
of which: | |||||||||||||||
impairment on deferred tax assets of Italian subsidiaries | 803 | 954 | 976 | ||||||||||||
other net tax refund | (824 | ) | |||||||||||||
deferred tax adjustment on PSAs | 552 | 490 | 69 | ||||||||||||
re-allocation of tax impact on intercompany dividends and other special items | 29 | 29 | 147 | 64 | (12 | ) | |||||||||
taxes on special items | (653 | ) | (521 | ) | (965 | ) | (607 | ) | (479 | ) | |||||
Total special items of net profit | 1,161 | 833 | (442 | ) | (1,173 | ) | 1,941 | ||||||||
attributable to: | |||||||||||||||
- non-controlling interest | (5 | ) | 533 | ||||||||||||
- Eni's shareholders | 1,161 | 833 | (442 | ) | (1,168 | ) | 1,408 |
(a) Including discontinued operations. |
Adjusted operating profit by segment |
(euro million) | 2010 |
2011 |
2012 |
2013 |
2014 |
Exploration & Production | 13,898 | 16,075 | 18,537 | 14,643 | 11,551 | ||||||||||
Gas & Power | 1,268 | (247 | ) | 398 | (638 | ) | 310 | ||||||||
Refining & Marketing | (181 | ) | (539 | ) | (289 | ) | (457 | ) | (208 | ) | |||||
Versalis | (96 | ) | (273 | ) | (483 | ) | (386 | ) | (346 | ) | |||||
Engineering & Construction | 1,326 | 1,443 | 1,485 | (99 | ) | 479 | |||||||||
Other activities | (205 | ) | (226 | ) | (222 | ) | (210 | ) | (178 | ) | |||||
Corporate and financial companies | (265 | ) | (266 | ) | (325 | ) | (332 | ) | (265 | ) | |||||
Impact of unrealized intragroup profit elimination | 1,100 | 1,263 | 782 | 129 | 231 | ||||||||||
16,845 | 17,230 | 19,883 | 12,650 | 11,574 |
- 77 -
Eni Fact Book Financial Data
Adjusted net profit by segment |
(euro million) | 2010 |
2011 |
2012 |
2013 |
2014 |
Exploration & Production | 5,609 | 6,865 | 7,426 | 5,950 | 4,423 | ||||||||||
Gas & Power | 1,267 | 252 | 479 | (253 | ) | 190 | |||||||||
Refining & Marketing | (56 | ) | (264 | ) | (181 | ) | (232 | ) | (147 | ) | |||||
Versalis | (73 | ) | (206 | ) | (395 | ) | (338 | ) | (277 | ) | |||||
Engineering & Construction | 994 | 1,098 | 1,111 | (253 | ) | 309 | |||||||||
Other activities | (216 | ) | (225 | ) | (247 | ) | (205 | ) | (200 | ) | |||||
Corporate and financial companies | (867 | ) | (753 | ) | (977 | ) | (484 | ) | (651 | ) | |||||
Impact of unrealized intragroup profit elimination | 1,124 | 1,146 | 661 | 39 | 152 | ||||||||||
7,782 | 7,913 | 7,877 | 4,224 | 3,799 | |||||||||||
of which attributable to: | |||||||||||||||
- non-controlling interest | 1,012 | 975 | 747 | (206 | ) | 92 | |||||||||
- Eni's shareholders | 6,770 | 6,938 | 7,130 | 4,430 | 3,707 |
Finance income (expense) |
(euro million) | 2010 |
2011 |
2012 |
2013 |
2014 |
Income from equity instruments | |||||||||||||||
Exchange differences, net | 92 | (111 | ) | 131 | 37 | (250 | ) | ||||||||
Finance income (expense) related to net borrowings and other | (634 | ) | (809 | ) | (1,101 | ) | (892 | ) | (856 | ) | |||||
Net income from securities | 10 | 9 | 9 | 8 | 9 | ||||||||||
Financial expense due to the passage of time (accretion discount) | (236 | ) | (235 | ) | (308 | ) | (240 | ) | (293 | ) | |||||
Income (expense) on derivatives | (131 | ) | (112 | ) | (252 | ) | (92 | ) | 162 | ||||||
less: | |||||||||||||||
finance expense capitalized | 150 | 112 | 150 | 170 | 163 | ||||||||||
(749 | ) | (1,146 | ) | (1,371 | ) | (1,009 | ) | (1,065 | ) | ||||||
of which, net income from receivables and securities held for financing operating activities and interest on tax credits | 64 | 67 | 46 | 58 | 111 |
Income (expense on) from investments |
(euro million) | 2010 |
2011 |
2012 |
2013 |
2014 |
Share of profit of equity-accounted investments | 673 | 634 | 451 | 313 | 215 | ||||||||||
Share of loss of equity-accounted investments | (149 | ) | (106 | ) | (250 | ) | (105 | ) | (86 | ) | |||||
Gains on disposals | 332 | 1,121 | 349 | 3,598 | 163 | ||||||||||
Dividends | 264 | 659 | 431 | 400 | 385 | ||||||||||
Decreases (increases) in the provision for losses on investments | (31 | ) | (28 | ) | (15 | ) | 14 | (8 | ) | ||||||
Other income (expense), net | 23 | (157 | ) | 1,823 | 1,865 | (179 | ) | ||||||||
1,112 | 2,123 | 2,789 | 6,085 | 490 |
- 78 -
Eni Fact Book Financial Data
Property, plant and equipment by segment (at year end) |
(euro million) | 2010 |
2011 |
2012 |
2013 |
2014 |
Property, plant and equipment by segment, gross | |||||||||||||||
Exploration & Production | 85,494 | 96,561 | 103,318 | 107,329 | 129,331 | ||||||||||
Gas & Power | 4,155 | 4,206 | 5,735 | 5,763 | 5,982 | ||||||||||
Refining & Marketing | 14,177 | 14,884 | 16,805 | 17,383 | 17,358 | ||||||||||
Versalis | 5,226 | 5,438 | 5,589 | 5,898 | 6,070 | ||||||||||
Engineering & Construction | 10,714 | 11,809 | 12,621 | 12,774 | 13,657 | ||||||||||
Other activities - Snam (*) | 18,355 | 19,449 | |||||||||||||
Other activities | 1,614 | 1,617 | 1,617 | 1,522 | 1,548 | ||||||||||
Corporate and financial companies | 372 | 422 | 470 | 589 | 653 | ||||||||||
Impact of unrealized intragroup profit elimination | (495 | ) | (523 | ) | (486 | ) | (490 | ) | (572 | ) | |||||
139,612 | 153,863 | 145,669 | 150,768 | 174,027 | |||||||||||
Property, plant and equipment by segment, net | |||||||||||||||
Exploration & Production | 40,521 | 45,527 | 47,509 | 48,134 | 56,654 | ||||||||||
Gas & Power | 2,614 | 2,501 | 3,356 | 1,969 | 1,984 | ||||||||||
Refining & Marketing | 4,766 | 4,758 | 4,851 | 4,575 | 4,461 | ||||||||||
Versalis | 990 | 960 | 928 | 1,105 | 1,193 | ||||||||||
Engineering & Construction | 7,422 | 7,969 | 8,213 | 7,928 | 7,616 | ||||||||||
Other activities - Snam (*) | 11,262 | 12,016 | |||||||||||||
Other activities | 78 | 76 | 76 | 72 | 74 | ||||||||||
Corporate and financial companies | 171 | 196 | 227 | 322 | 378 | ||||||||||
Impact of unrealized intragroup profit elimination | (420 | ) | (425 | ) | (362 | ) | (342 | ) | (398 | ) | |||||
67,404 | 73,578 | 64,798 | 63,763 | 71,962 |
(*) Property, plant and equipment pertaining to the segment Other activities - Snam has been reclassified from the Gas & Power segment. |
Capital expenditure by segment |
(euro million) | 2010 |
2011 |
2012 |
2013 |
2014 |
Exploration & Production | 9,690 | 9,435 | 10,307 | 10,475 | 10,524 | ||||||||||
Gas & Power | 265 | 192 | 213 | 229 | 172 | ||||||||||
Refining & Marketing | 711 | 866 | 898 | 672 | 537 | ||||||||||
Versalis | 251 | 216 | 172 | 314 | 282 | ||||||||||
Engineering & Construction | 1,552 | 1,090 | 1,011 | 902 | 694 | ||||||||||
Other activities | 22 | 10 | 14 | 21 | 30 | ||||||||||
Corporate and financial companies | 109 | 128 | 152 | 190 | 83 | ||||||||||
Impact of unrealized intragroup profit elimination | (150 | ) | (28 | ) | 38 | (3 | ) | (82 | ) | ||||||
Capital expenditure - continuing operations | 12,450 | 11,909 | 12,805 | 12,800 | 12,240 | ||||||||||
Capital expenditure - discontinued operations | 1,420 | 1,529 | 756 | ||||||||||||
Capital expenditure | 13,870 | 13,438 | 13,561 | 12,800 | 12,240 | ||||||||||
Investments | 410 | 360 | 569 | 317 | 408 | ||||||||||
Capital expenditure and investments | 14,280 | 13,798 | 14,130 | 13,117 | 12,648 |
Capital expenditure by geographic area of origin |
(euro million) | 2010 |
2011 |
2012 |
2013 |
2014 |
Italy | 1,624 | 2,058 | 2,170 | 2,044 | 1,785 | ||||||
Other European Union countries | 1,710 | 1,343 | 1,263 | 1,089 | 853 | ||||||
Rest of Europe | 724 | 1,168 | 1,626 | 1,553 | 1,407 | ||||||
Africa | 5,083 | 4,369 | 4,725 | 4,556 | 4,864 | ||||||
Americas | 1,156 | 978 | 1,184 | 1,506 | 1,196 | ||||||
Asia | 1,941 | 1,608 | 1,663 | 1,799 | 1,974 | ||||||
Other areas | 212 | 385 | 174 | 253 | 161 | ||||||
Total outside Italy | 10,826 | 9,851 | 10,635 | 10,756 | 10,455 | ||||||
Capital expenditure - continuing operations | 12,450 | 11,909 | 12,805 | 12,800 | 12,240 | ||||||
Capital expenditure - discontinued operations | |||||||||||
Italy | 1,420 | 1,529 | 756 | ||||||||
Capital expenditure | 13,870 | 13,438 | 13,561 | 12,800 | 12,240 |
- 79 -
Eni Fact Book Financial Data
Net borrowings | (euro million) |
Debt and bonds | Cash and cash equivalents | Securities held for trading and other securities held for non-operating purposes | Financing receivables held for non-operating purposes | Total | ||||||
2010 | ||||||||||||||
Short-term debt | 7,478 | (1,549 | ) | (109 | ) | (6 | ) | 5,814 | ||||||
Long-term debt | 20,305 | 20,305 | ||||||||||||
27,783 | (1,549 | ) | (109 | ) | (6 | ) | 26,119 | |||||||
2011 | ||||||||||||||
Short-term debt | 6,495 | (1,500 | ) | (37 | ) | (28 | ) | 4,930 | ||||||
Long-term debt | 23,102 | 23,102 | ||||||||||||
29,597 | (1,500 | ) | (37 | ) | (28 | ) | 28,032 | |||||||
2012 | ||||||||||||||
Short-term debt | 5,047 | (7,936 | ) | (36 | ) | (1,151 | ) | (4,076 | ) | |||||
Long-term debt | 19,145 | 19,145 | ||||||||||||
24,192 | (7,936 | ) | (36 | ) | (1,151 | ) | 15,069 | |||||||
2013 | ||||||||||||||
Short-term debt | 4,685 | (5,431 | ) | (5,037 | ) | (129 | ) | (5,912 | ) | |||||
Long-term debt | 20,875 | 20,875 | ||||||||||||
25,560 | (5,431 | ) | (5,037 | ) | (129 | ) | 14,963 | |||||||
2014 | ||||||||||||||
Short-term debt | 6,575 | (6,614 | ) | (5,037 | ) | (555 | ) | (5,631 | ) | |||||
Long-term debt | 19,316 | 19,316 | ||||||||||||
25,891 | (6,614 | ) | (5,037 | ) | (555 | ) | 13,685 |
- 80 -
Eni Fact Book Employees
Employees
Employees at year end (*) |
2010 |
2011 |
2012 |
2013 |
2014 |
Italy | 3,906 | 3,797 | 3,933 | 4,133 | 4,534 | ||||||||
Exploration & Production | Outside Italy | 6,370 | 6,628 | 7,371 | 8,219 | 8,243 | |||||||
10,276 | 10,425 | 11,304 | 12,352 | 12,777 | |||||||||
Italy | 2,479 | 2,310 | 2,126 | 2,178 | 1,980 | ||||||||
Gas & Power | Outside Italy | 2,593 | 2,485 | 2,710 | 2,438 | 2,248 | |||||||
5,072 | 4,795 | 4,836 | 4,616 | 4,228 | |||||||||
Italy | 6,162 | 5,790 | 6,098 | 5,909 | 4,897 | ||||||||
Refining & Marketing | Outside Italy | 1,860 | 1,801 | 2,510 | 2,529 | 1,877 | |||||||
8,022 | 7,591 | 8,608 | 8,438 | 6,774 | |||||||||
Italy | 4,903 | 4,750 | 4,606 | 4,615 | 4,476 | ||||||||
Versalis | Outside Italy | 1,069 | 1,054 | 1,062 | 1,093 | 967 | |||||||
5,972 | 5,804 | 5,668 | 5,708 | 5,443 | |||||||||
Italy | 4,915 | 5,197 | 5,186 | 5,136 | 5,016 | ||||||||
Engineering & Construction | Outside Italy | 33,911 | 33,364 | 38,201 | 42,073 | 44,543 | |||||||
38,826 | 38,561 | 43,387 | 47,209 | 49,559 | |||||||||
Italy | 939 | 880 | 871 | 818 | 726 | ||||||||
Other activities | Outside Italy | - | - | - | - | - | |||||||
939 | 880 | 871 | 818 | 726 | |||||||||
Italy | 4,497 | 4,334 | 4,577 | 4,589 | 4,594 | ||||||||
Corporate and financial companies | Outside Italy | 164 | 184 | 154 | 157 | 304 | |||||||
4,661 | 4,518 | 4,731 | 4,746 | 4,898 | |||||||||
Italy | 27,801 | 27,058 | 27,397 | 27,378 | 26,223 | ||||||||
Total employees at year end | Outside Italy | 45,967 | 45,516 | 52,008 | 56,509 | 58,182 | |||||||
73,768 | 72,574 | 79,405 | 83,887 | 84,405 | |||||||||
of which: senior managers | 1,454 | 1,468 | 1,504 | 1,505 | 1,503 |
(*) 2012, 2013 and 2014 data include employees of consolidated subsidiaries and equity accounted entities.
- 81 -
Eni Fact Book Supplemental oil and gas information
Supplemental oil and gas information
Oil and natural gas reserves Enis
criteria concerning evaluation and classification of
proved developed and undeveloped reserves follow
Regulation S-X 4-10 of the US Securities and Exchange
Commission and have been disclosed in accordance with
FASB Extractive Activities - Oil & Gas (Topic 932). |
hydrocarbon sales, price
adjustments required by applicable contractual
arrangements, and other pertinent information are
provided. In 2014, Ryder Scott Company and DeGolyer and
MacNaughton2 provided an independent
evaluation of about 27% of Enis total proved
reserves as of December 31, 20143, confirming,
as in previous years, the reasonableness of Enis
internal evaluations. In the three-year period from 2012
to 2014, 94% of Enis total proved reserves were
subject to independent evaluation. As of December 31,
2014, the principal properties not subjected to
independent evaluation in the last three years are
MBoundi (Congo) and Junin 5 (Venezuela). Eni
operates under production sharing agreements, in several
of the foreign jurisdictions where it has oil and gas
exploration and production activities. Reserves of oil
and natural gas to which Eni is entitled under PSAs
arrangements are shown in accordance with Enis
economic interest in the volumes of oil and natural gas
estimated to be recoverable in future years. Such reserves include estimated quantities allocated to Eni for recovery of costs, income taxes owed by Eni but settled by its joint venture partners (which are state-owned entities) out of Enis share of production and Enis net equity share after cost recovery. Proved oil and gas reserves associated with PSAs represented 47%, 51% and 50% of total proved reserves as of December 31, 2012, 2013 and 2014, respectively, on an oil-equivalent basis. Similar effects as PSAs apply to service and "buy-back" contracts; proved reserves associated with such contracts represented 2%, 3% and 3% of total proved reserves on an oil-equivalent basis as of December 31, 2012, 2013 and 2014, respectively. Oil and gas reserves quantities include: (i) oil and natural gas quantities in excess of cost recovery which the Company has an obligation to purchase under certain PSAs with governments or authorities, whereby the Company serves as producer of reserves. Reserves volumes associated with oil and gas deriving from such obligation represent 1.1%, 1% and 0.6% of total proved reserves as of December 31, 2012, 2013 and 2014, respectively, on an oil equivalent basis; (ii) volumes of natural gas used for own consumption; and (iii) the quantities of hydrocarbons related to the Angola LNG plant. Numerous uncertainties are inherent in estimating quantities of proved reserves, in projecting future productions and development expenditures. The accuracy of any reserve estimate is a function of the quality of available data and engineering and geological interpretation and evaluation. The results of drilling, testing and production after the date of the estimate may require substantial upward or downward revisions. In addition, changes in oil and natural gas prices have an effect on the quantities of Enis proved reserves since estimates of reserves are based on prices and costs relevant to the date when such estimates are made. Consequently, the evaluation of reserves could also significantly differ from actual oil and natural gas volumes that will be produced. The following table presents yearly changes in estimated proved reserves, developed and undeveloped, of crude oil (including condensate and natural gas liquids) and natural gas as of December 31, 2012, 2013 and 2014. |
(1) From 1991 to
2002 DeGolyer and MacNaughton, from 2003 also Ryder Scott.
(2) The reports of independent engineers are available on Eni
website eni.com, section Publications/Annual Report 2014.
(3) Including reserves of equity-accounted entities.
- 82 -
Eni Fact Book Supplemental oil and gas information
Movements in net proved hydrocarbons reserves | (mmboe) |
Italy (a) | Rest of Europe | North Africa | Sub-Saharan Africa | Kazakhstan | Rest of Asia | Americas | Australia and Oceania | Total | ||||||||||
2012 | |||||||||||||||||||||||||||
Consolidated subsidiaries | |||||||||||||||||||||||||||
Reserves at December 31, 2011 | 707 | 630 | 2,031 | 1,021 | 950 | 230 | 238 | 133 | 5,940 | ||||||||||||||||||
of which: | |||||||||||||||||||||||||||
developed | 540 | 374 | 1,175 | 742 | 482 | 129 | 162 | 112 | 3,716 | ||||||||||||||||||
undeveloped | 167 | 256 | 856 | 279 | 468 | 101 | 76 | 21 | 2,224 | ||||||||||||||||||
Purchase of minerals in place | |||||||||||||||||||||||||||
Revisions of previous estimates | 24 | 20 | 67 | 82 | 91 | (5 | ) | 34 | 8 | 321 | |||||||||||||||||
Improved recovery | 1 | 20 | 7 | 28 | |||||||||||||||||||||||
Extensions and discoveries | 4 | 6 | 10 | 86 | 85 | 9 | 200 | ||||||||||||||||||||
Production | (69 | ) | (66 | ) | (213 | ) | (126 | ) | (37 | ) | (41 | ) | (45 | ) | (13 | ) | (610 | ) | |||||||||
Sales of minerals in place | (142 | ) | (22 | ) | (48 | ) | (212 | ) | |||||||||||||||||||
Reserves at December 31, 2012 | 524 | 591 | 1,915 | 1,048 | 1,041 | 184 | 236 | 128 | 5,667 | ||||||||||||||||||
Equity-accounted entities | |||||||||||||||||||||||||||
Reserves at December 31, 2011 | 21 | 83 | 656 | 386 | 1,146 | ||||||||||||||||||||||
of which: | |||||||||||||||||||||||||||
developed | 19 | 4 | 5 | 26 | 54 | ||||||||||||||||||||||
undeveloped | 2 | 79 | 651 | 360 | 1,092 | ||||||||||||||||||||||
Purchase of minerals in place | |||||||||||||||||||||||||||
Revisions of previous estimates | 8 | 247 | 255 | ||||||||||||||||||||||||
Improved recovery | |||||||||||||||||||||||||||
Extensions and discoveries | 1 | 3 | 10 | 135 | 149 | ||||||||||||||||||||||
Production | (2 | ) | (1 | ) | (6 | ) | (4 | ) | (13 | ) | |||||||||||||||||
Sales of minerals in place | (4 | ) | (34 | ) | (38 | ) | |||||||||||||||||||||
Reserves at December 31, 2012 | 20 | 81 | 668 | 730 | 1,499 | ||||||||||||||||||||||
Reserves at December 31, 2012 | 524 | 591 | 1,935 | 1,129 | 1,041 | 852 | 966 | 128 | 7,166 | ||||||||||||||||||
Developed | 406 | 349 | 1,100 | 716 | 458 | 190 | 190 | 107 | 3,516 | ||||||||||||||||||
consolidated subsidiaries | 406 | 349 | 1,080 | 716 | 458 | 108 | 170 | 107 | 3,394 | ||||||||||||||||||
equity-accounted entities | 20 | 82 | 20 | 122 | |||||||||||||||||||||||
Undeveloped | 118 | 242 | 835 | 413 | 583 | 662 | 776 | 21 | 3,650 | ||||||||||||||||||
consolidated subsidiaries | 118 | 242 | 835 | 332 | 583 | 76 | 66 | 21 | 2,273 | ||||||||||||||||||
equity-accounted entities | 81 | 586 | 710 | 1,377 |
(a) Including approximately 767 billion cubic feet of natural gas held in storage at December 31, 2011. |
- 83 -
Eni Fact Book Supplemental oil and gas information
Movements in net proved hydrocarbons reserves | (mmboe) |
Italy | Rest of Europe | North Africa | Sub-Saharan Africa | Kazakhstan | Rest of Asia | Americas | Australia and Oceania | Total | ||||||||||
2013 | |||||||||||||||||||||||||||
Consolidated subsidiaries | |||||||||||||||||||||||||||
Reserves at December 31, 2012 | 524 | 591 | 1,915 | 1,048 | 1,041 | 184 | 236 | 128 | 5,667 | ||||||||||||||||||
of which: | |||||||||||||||||||||||||||
developed | 406 | 349 | 1,080 | 716 | 458 | 108 | 170 | 107 | 3,394 | ||||||||||||||||||
undeveloped | 118 | 242 | 835 | 332 | 583 | 76 | 66 | 21 | 2,273 | ||||||||||||||||||
Purchase of minerals in place | 4 | 4 | |||||||||||||||||||||||||
Revisions of previous estimates | 38 | 35 | 59 | 169 | 30 | 81 | 37 | 59 | 508 | ||||||||||||||||||
Improved recovery | 5 | 5 | |||||||||||||||||||||||||
Extensions and discoveries | 4 | 1 | 6 | 53 | 38 | 6 | 108 | ||||||||||||||||||||
Production | (67 | ) | (57 | ) | (201 | ) | (120 | ) | (36 | ) | (40 | ) | (39 | ) | (11 | ) | (571 | ) | |||||||||
Sales of minerals in place | (13 | ) | (13 | ) | |||||||||||||||||||||||
Reserves at December 31, 2013 | 499 | 557 | 1,783 | 1,155 | 1,035 | 263 | 240 | 176 | 5,708 | ||||||||||||||||||
Equity-accounted entities | |||||||||||||||||||||||||||
Reserves at December 31, 2012 | 20 | 81 | 668 | 730 | 1,499 | ||||||||||||||||||||||
of which: | |||||||||||||||||||||||||||
developed | 20 | 82 | 20 | 122 | |||||||||||||||||||||||
undeveloped | 81 | 586 | 710 | 1,377 | |||||||||||||||||||||||
Purchase of minerals in place | 1 | (5 | ) | 4 | |||||||||||||||||||||||
Revisions of previous estimates | |||||||||||||||||||||||||||
Improved recovery | |||||||||||||||||||||||||||
Extensions and discoveries | |||||||||||||||||||||||||||
Production | (2 | ) | (1 | ) | (13 | ) | (4 | ) | (20 | ) | |||||||||||||||||
Sales of minerals in place | (652 | ) | (652 | ) | |||||||||||||||||||||||
Reserves at December 31, 2013 | 19 | 75 | 7 | 726 | 827 | ||||||||||||||||||||||
Reserves at December 31, 2013 | 499 | 557 | 1,802 | 1,230 | 1,035 | 270 | 966 | 176 | 6,535 | ||||||||||||||||||
Developed | 408 | 343 | 1,022 | 701 | 566 | 93 | 171 | 123 | 3,427 | ||||||||||||||||||
consolidated subsidiaries | 408 | 343 | 1,003 | 701 | 566 | 90 | 153 | 123 | 3,387 | ||||||||||||||||||
equity-accounted entities | 19 | 3 | 18 | 40 | |||||||||||||||||||||||
Undeveloped | 91 | 214 | 780 | 529 | 469 | 177 | 795 | 53 | 3,108 | ||||||||||||||||||
consolidated subsidiaries | 91 | 214 | 780 | 454 | 469 | 173 | 87 | 53 | 2,321 | ||||||||||||||||||
equity-accounted entities | 75 | 4 | 708 | 787 |
- 84 -
Eni Fact Book Supplemental oil and gas information
Movements in net proved hydrocarbons reserves | (mmboe) |
Italy | Rest of Europe | North Africa | Sub-Saharan Africa | Kazakhstan | Rest of Asia | Americas | Australia and Oceania | Total | ||||||||||
2014 | |||||||||||||||||||||||||||
Consolidated subsidiaries | |||||||||||||||||||||||||||
Reserves at December 31, 2013 | 499 | 557 | 1,783 | 1,155 | 1,035 | 263 | 240 | 176 | 5,708 | ||||||||||||||||||
of which: | |||||||||||||||||||||||||||
developed | 408 | 343 | 1,003 | 701 | 566 | 90 | 153 | 123 | 3,387 | ||||||||||||||||||
undeveloped | 91 | 214 | 780 | 454 | 469 | 173 | 87 | 53 | 2,321 | ||||||||||||||||||
Purchase of minerals in place | 4 | 4 | |||||||||||||||||||||||||
Revisions of previous estimates | 68 | 53 | 154 | 110 | 64 | 45 | 26 | (7 | ) | 513 | |||||||||||||||||
Improved recovery | 3 | 1 | 2 | 6 | |||||||||||||||||||||||
Extensions and discoveries | 1 | 1 | 5 | 98 | 11 | 8 | 124 | ||||||||||||||||||||
Production | (65 | ) | (70 | ) | (205 | ) | (118 | ) | (32 | ) | (34 | ) | (42 | ) | (9 | ) | (575 | ) | |||||||||
Sales of minerals in place | (1 | ) | (7 | ) | (8 | ) | |||||||||||||||||||||
Reserves at December 31, 2014 | 503 | 544 | 1,740 | 1,239 | 1,069 | 285 | 232 | 160 | 5,772 | ||||||||||||||||||
Equity-accounted entities | |||||||||||||||||||||||||||
Reserves at December 31, 2013 | 19 | 75 | 7 | 726 | 827 | ||||||||||||||||||||||
of which: | |||||||||||||||||||||||||||
developed | 19 | 3 | 18 | 40 | |||||||||||||||||||||||
undeveloped | 75 | 4 | 708 | 787 | |||||||||||||||||||||||
Purchase of minerals in place | |||||||||||||||||||||||||||
Revisions of previous estimates | (1 | ) | 7 | 5 | 11 | ||||||||||||||||||||||
Improved recovery | |||||||||||||||||||||||||||
Extensions and discoveries | |||||||||||||||||||||||||||
Production | (2 | ) | (1 | ) | (2 | ) | (3 | ) | (8 | ) | |||||||||||||||||
Sales of minerals in place | |||||||||||||||||||||||||||
Reserves at December 31, 2014 | 16 | 81 | 5 | 728 | 830 | ||||||||||||||||||||||
Reserves at December 31, 2014 | 503 | 544 | 1,756 | 1,320 | 1,069 | 290 | 960 | 160 | 6,602 | ||||||||||||||||||
Developed | 401 | 335 | 919 | 725 | 589 | 115 | 214 | 135 | 3,433 | ||||||||||||||||||
consolidated subsidiaries | 401 | 335 | 904 | 702 | 589 | 112 | 188 | 135 | 3,366 | ||||||||||||||||||
equity-accounted entities | 15 | 23 | 3 | 26 | 67 | ||||||||||||||||||||||
Undeveloped | 102 | 209 | 837 | 595 | 480 | 175 | 746 | 25 | 3,169 | ||||||||||||||||||
consolidated subsidiaries | 102 | 209 | 836 | 537 | 480 | 173 | 44 | 25 | 2,406 | ||||||||||||||||||
equity-accounted entities | 1 | 58 | 2 | 702 | 763 |
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Eni Fact Book Supplemental oil and gas information
Movements in net proved liquids reserves | (mmbbl) |
Italy | Rest of Europe | North Africa | Sub-Saharan Africa | Kazakhstan | Rest of Asia | Americas | Australia and Oceania | Total | ||||||||||
2012 | |||||||||||||||||||||||||||
Consolidated subsidiaries | |||||||||||||||||||||||||||
Reserves at December 31, 2011 | 259 | 372 | 917 | 670 | 653 | 106 | 132 | 25 | 3,134 | ||||||||||||||||||
of which: | |||||||||||||||||||||||||||
developed | 184 | 195 | 622 | 483 | 215 | 34 | 92 | 25 | 1,850 | ||||||||||||||||||
undeveloped | 75 | 177 | 295 | 187 | 438 | 72 | 40 | 1,284 | |||||||||||||||||||
Purchase of minerals in place | |||||||||||||||||||||||||||
Revisions of previous estimates | (9 | ) | 10 | 55 | 26 | 62 | (9 | ) | 40 | 6 | 181 | ||||||||||||||||
Improved recovery | 1 | 20 | 7 | 28 | |||||||||||||||||||||||
Extensions and discoveries | 3 | 10 | 65 | 8 | 86 | ||||||||||||||||||||||
Production | (23 | ) | (35 | ) | (98 | ) | (90 | ) | (22 | ) | (15 | ) | (26 | ) | (7 | ) | (316 | ) | |||||||||
Sales of minerals in place | (6 | ) | (23 | ) | (29 | ) | |||||||||||||||||||||
Reserves at December 31, 2012 | 227 | 351 | 904 | 672 | 670 | 82 | 154 | 24 | 3,084 | ||||||||||||||||||
Equity-accounted entities | |||||||||||||||||||||||||||
Reserves at December 31, 2011 | 17 | 22 | 110 | 151 | 300 | ||||||||||||||||||||||
of which: | |||||||||||||||||||||||||||
developed | 16 | 4 | 25 | 45 | |||||||||||||||||||||||
undeveloped | 1 | 18 | 110 | 126 | 255 | ||||||||||||||||||||||
Purchase of minerals in place | |||||||||||||||||||||||||||
Revisions of previous estimates | (1 | ) | 2 | 1 | |||||||||||||||||||||||
Improved recovery | |||||||||||||||||||||||||||
Extensions and discoveries | 1 | 3 | 4 | ||||||||||||||||||||||||
Production | (1 | ) | (1 | ) | (1 | ) | (4 | ) | (7 | ) | |||||||||||||||||
Sales of minerals in place | (4 | ) | (28 | ) | (32 | ) | |||||||||||||||||||||
Reserves at December 31, 2012 | 17 | 16 | 114 | 119 | 266 | ||||||||||||||||||||||
Reserves at December 31, 2012 | 227 | 351 | 921 | 688 | 670 | 196 | 273 | 24 | 3,350 | ||||||||||||||||||
Developed | 165 | 180 | 601 | 456 | 203 | 49 | 128 | 24 | 1,806 | ||||||||||||||||||
consolidated subsidiaries | 165 | 180 | 584 | 456 | 203 | 41 | 109 | 24 | 1,762 | ||||||||||||||||||
equity-accounted entities | 17 | 8 | 19 | 44 | |||||||||||||||||||||||
Undeveloped | 62 | 171 | 320 | 232 | 467 | 147 | 145 | 1,544 | |||||||||||||||||||
consolidated subsidiaries | 62 | 171 | 320 | 216 | 467 | 41 | 45 | 1,322 | |||||||||||||||||||
equity-accounted entities | 16 | 106 | 100 | 222 |
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Eni Fact Book Supplemental oil and gas information
Movements in net proved liquids reserves | (mmbbl) |
Italy | Rest of Europe | North Africa | Sub-Saharan Africa | Kazakhstan | Rest of Asia | Americas | Australia and Oceania | Total | ||||||||||
2013 | |||||||||||||||||||||||||||
Consolidated subsidiaries | |||||||||||||||||||||||||||
Reserves at December 31, 2012 | 227 | 351 | 904 | 672 | 670 | 82 | 154 | 24 | 3,084 | ||||||||||||||||||
of which: | |||||||||||||||||||||||||||
developed | 165 | 180 | 584 | 456 | 203 | 41 | 109 | 24 | 1,762 | ||||||||||||||||||
undeveloped | 62 | 171 | 320 | 216 | 467 | 41 | 45 | 1,322 | |||||||||||||||||||
Purchase of minerals in place | 3 | 3 | |||||||||||||||||||||||||
Revisions of previous estimates | 19 | 16 | 12 | 83 | 31 | 62 | 11 | 2 | 236 | ||||||||||||||||||
Improved recovery | 5 | 5 | |||||||||||||||||||||||||
Extensions and discoveries | 1 | 2 | 51 | 4 | 58 | ||||||||||||||||||||||
Production | (26 | ) | (28 | ) | (91 | ) | (88 | ) | (22 | ) | (16 | ) | (22 | ) | (4 | ) | (297 | ) | |||||||||
Sales of minerals in place | (10 | ) | (10 | ) | |||||||||||||||||||||||
Reserves at December 31, 2013 | 220 | 330 | 830 | 723 | 679 | 128 | 147 | 22 | 3,079 | ||||||||||||||||||
Equity-accounted entities | |||||||||||||||||||||||||||
Reserves at December 31, 2012 | 17 | 16 | 114 | 119 | 266 | ||||||||||||||||||||||
of which: | |||||||||||||||||||||||||||
developed | 17 | 8 | 19 | 44 | |||||||||||||||||||||||
undeveloped | 16 | 106 | 100 | 222 | |||||||||||||||||||||||
Purchase of minerals in place | |||||||||||||||||||||||||||
Revisions of previous estimates | (1 | ) | 1 | ||||||||||||||||||||||||
Improved recovery | |||||||||||||||||||||||||||
Extensions and discoveries | |||||||||||||||||||||||||||
Production | (1 | ) | (2 | ) | (4 | ) | (7 | ) | |||||||||||||||||||
Sales of minerals in place | (111 | ) | (111 | ) | |||||||||||||||||||||||
Reserves at December 31, 2013 | 16 | 15 | 1 | 116 | 148 | ||||||||||||||||||||||
Reserves at December 31, 2013 | 220 | 330 | 846 | 738 | 679 | 129 | 263 | 22 | 3,227 | ||||||||||||||||||
Developed | 177 | 179 | 577 | 465 | 295 | 38 | 115 | 20 | 1,866 | ||||||||||||||||||
consolidated subsidiaries | 177 | 179 | 561 | 465 | 295 | 38 | 96 | 20 | 1,831 | ||||||||||||||||||
equity-accounted entities | 16 | 19 | 35 | ||||||||||||||||||||||||
Undeveloped | 43 | 151 | 269 | 273 | 384 | 91 | 148 | 2 | 1,361 | ||||||||||||||||||
consolidated subsidiaries | 43 | 151 | 269 | 258 | 384 | 90 | 51 | 2 | 1,248 | ||||||||||||||||||
equity-accounted entities | 15 | 1 | 97 | 113 |
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Eni Fact Book Supplemental oil and gas information
Movements in net proved liquids reserves | (mmbbl) |
Italy | Rest of Europe | North Africa | Sub-Saharan Africa | Kazakhstan | Rest of Asia | Americas | Australia and Oceania | Total | ||||||||||
2014 | |||||||||||||||||||||||||||
Consolidated subsidiaries | |||||||||||||||||||||||||||
Reserves at December 31, 2013 | 220 | 330 | 830 | 723 | 679 | 128 | 147 | 22 | 3,079 | ||||||||||||||||||
of which: | |||||||||||||||||||||||||||
developed | 177 | 179 | 561 | 465 | 295 | 38 | 96 | 20 | 1,831 | ||||||||||||||||||
undeveloped | 43 | 151 | 269 | 258 | 384 | 90 | 51 | 2 | 1,248 | ||||||||||||||||||
Purchase of minerals in place | 1 | 1 | |||||||||||||||||||||||||
Revisions of previous estimates | 49 | 35 | 32 | 70 | 35 | 16 | 22 | (7 | ) | 252 | |||||||||||||||||
Improved recovery | 3 | 1 | 2 | 6 | |||||||||||||||||||||||
Extensions and discoveries | 1 | 2 | 36 | 5 | 44 | ||||||||||||||||||||||
Production | (27 | ) | (34 | ) | (91 | ) | (84 | ) | (19 | ) | (13 | ) | (27 | ) | (2 | ) | (297 | ) | |||||||||
Sales of minerals in place | (1 | ) | (7 | ) | (8 | ) | |||||||||||||||||||||
Reserves at December 31, 2014 | 243 | 331 | 776 | 739 | 697 | 131 | 147 | 13 | 3,077 | ||||||||||||||||||
Equity-accounted entities | |||||||||||||||||||||||||||
Reserves at December 31, 2013 | 16 | 15 | 1 | 116 | 148 | ||||||||||||||||||||||
of which: | |||||||||||||||||||||||||||
developed | 16 | 19 | 35 | ||||||||||||||||||||||||
undeveloped | 15 | 1 | 97 | 113 | |||||||||||||||||||||||
Purchase of minerals in place | |||||||||||||||||||||||||||
Revisions of previous estimates | (1 | ) | 3 | 5 | 7 | ||||||||||||||||||||||
Improved recovery | |||||||||||||||||||||||||||
Extensions and discoveries | |||||||||||||||||||||||||||
Production | (1 | ) | (1 | ) | (4 | ) | (6 | ) | |||||||||||||||||||
Sales of minerals in place | |||||||||||||||||||||||||||
Reserves at December 31, 2014 | 14 | 17 | 1 | 117 | 149 | ||||||||||||||||||||||
Reserves at December 31, 2014 | 243 | 331 | 790 | 756 | 697 | 132 | 264 | 13 | 3,226 | ||||||||||||||||||
Developed | 184 | 174 | 534 | 477 | 306 | 64 | 142 | 12 | 1,893 | ||||||||||||||||||
consolidated subsidiaries | 184 | 174 | 521 | 470 | 306 | 64 | 116 | 12 | 1,847 | ||||||||||||||||||
equity-accounted entities | 13 | 7 | 26 | 46 | |||||||||||||||||||||||
Undeveloped | 59 | 157 | 256 | 279 | 391 | 68 | 122 | 1 | 1,333 | ||||||||||||||||||
consolidated subsidiaries | 59 | 157 | 255 | 269 | 391 | 67 | 31 | 1 | 1,230 | ||||||||||||||||||
equity-accounted entities | 1 | 10 | 1 | 91 | 103 |
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Eni Fact Book Supplemental oil and gas information
Movements in net proved natural gas reserves | (bcf) |
Italy (a) | Rest of Europe | North Africa | Sub-Saharan Africa | Kazakhstan | Rest of Asia | Americas | Australia and Oceania | Total | ||||||||||
2012 | |||||||||||||||||||||||||||
Consolidated subsidiaries | |||||||||||||||||||||||||||
Reserves at December 31, 2011 | 2,491 | 1,425 | 6,190 | 1,949 | 1,648 | 685 | 590 | 604 | 15,582 | ||||||||||||||||||
of which: | |||||||||||||||||||||||||||
developed | 1,977 | 995 | 3,070 | 1,437 | 1,480 | 528 | 385 | 491 | 10,363 | ||||||||||||||||||
undeveloped | 514 | 430 | 3,120 | 512 | 168 | 157 | 205 | 113 | 5,219 | ||||||||||||||||||
Purchase of minerals in place | |||||||||||||||||||||||||||
Revisions of previous estimates | 154 | 45 | 284 | 141 | 18 | (41 | ) | 5 | 606 | ||||||||||||||||||
Improved recovery | |||||||||||||||||||||||||||
Extensions and discoveries | 24 | 15 | 1 | 113 | 469 | 2 | 4 | 628 | |||||||||||||||||||
Production | (254 | ) | (168 | ) | (633 | ) | (196 | ) | (81 | ) | (143 | ) | (104 | ) | (37 | ) | (1,616 | ) | |||||||||
Sales of minerals in place | (782 | ) | (89 | ) | (139 | ) | (1,010 | ) | |||||||||||||||||||
Reserves at December 31, 2012 | 1,633 | 1,317 | 5,558 | 2,061 | 2,038 | 562 | 449 | 572 | 14,190 | ||||||||||||||||||
Equity-accounted entities | |||||||||||||||||||||||||||
Reserves at December 31, 2011 | 2 | 20 | 338 | 3,033 | 1,307 | 4,700 | |||||||||||||||||||||
of which: | |||||||||||||||||||||||||||
developed | 17 | 4 | 24 | 8 | 53 | ||||||||||||||||||||||
undeveloped | 2 | 3 | 334 | 3,009 | 1,299 | 4,647 | |||||||||||||||||||||
Purchase of minerals in place | |||||||||||||||||||||||||||
Revisions of previous estimates | (2 | ) | (2 | ) | 3 | 1 | 1,340 | 1,340 | |||||||||||||||||||
Improved recovery | |||||||||||||||||||||||||||
Extensions and discoveries | 17 | 38 | 739 | 794 | |||||||||||||||||||||||
Production | (2 | ) | (2 | ) | (29 | ) | (33 | ) | |||||||||||||||||||
Sales of minerals in place | (3 | ) | (31 | ) | (34 | ) | |||||||||||||||||||||
Reserves at December 31, 2012 | 16 | 353 | 3,043 | 3,355 | 6,767 | ||||||||||||||||||||||
Reserves at December 31, 2012 | 1,633 | 1,317 | 5,574 | 2,414 | 2,038 | 3,605 | 3,804 | 572 | 20,957 | ||||||||||||||||||
Developed | 1,325 | 925 | 2,736 | 1,429 | 1,401 | 774 | 340 | 459 | 9,389 | ||||||||||||||||||
consolidated subsidiaries | 1,325 | 925 | 2,720 | 1,429 | 1,401 | 372 | 334 | 459 | 8,965 | ||||||||||||||||||
equity-accounted entities | 16 | 402 | 6 | 424 | |||||||||||||||||||||||
Undeveloped | 308 | 392 | 2,838 | 985 | 637 | 2,831 | 3,464 | 113 | 11,568 | ||||||||||||||||||
consolidated subsidiaries | 308 | 392 | 2,838 | 632 | 637 | 190 | 115 | 113 | 5,225 | ||||||||||||||||||
equity-accounted entities | 353 | 2,641 | 3,349 | 6,343 |
(a) Including approximately 767 billion cubic feet of natural gas held in storage at December 31, 2011. |
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Eni Fact Book Supplemental oil and gas information
Movements in net proved natural gas reserves | (bcf) |
Italy | Rest of Europe | North Africa | Sub-Saharan Africa | Kazakhstan | Rest of Asia | Americas | Australia and Oceania | Total | ||||||||||
2013 | |||||||||||||||||||||||||||
Consolidated subsidiaries | |||||||||||||||||||||||||||
Reserves at December 31, 2012 | 1,633 | 1,317 | 5,558 | 2,061 | 2,038 | 562 | 449 | 572 | 14,190 | ||||||||||||||||||
of which: | |||||||||||||||||||||||||||
developed | 1,325 | 925 | 2,720 | 1,429 | 1,401 | 372 | 334 | 459 | 8,965 | ||||||||||||||||||
undeveloped | 308 | 392 | 2,838 | 632 | 637 | 190 | 115 | 113 | 5,225 | ||||||||||||||||||
Purchase of minerals in place | 5 | 5 | |||||||||||||||||||||||||
Revisions of previous estimates | 105 | 103 | 253 | 475 | (3 | ) | 104 | 142 | 316 | 1,495 | |||||||||||||||||
Improved recovery | |||||||||||||||||||||||||||
Extensions and discoveries | 24 | 1 | 24 | 14 | 208 | 7 | 278 | ||||||||||||||||||||
Production | (230 | ) | (157 | ) | (609 | ) | (176 | ) | (78 | ) | (130 | ) | (89 | ) | (40 | ) | (1,509 | ) | |||||||||
Sales of minerals in place | (17 | ) | (17 | ) | |||||||||||||||||||||||
Reserves at December 31, 2013 | 1,532 | 1,247 | 5,231 | 2,374 | 1,957 | 744 | 509 | 848 | 14,442 | ||||||||||||||||||
Equity-accounted entities | |||||||||||||||||||||||||||
Reserves at December 31, 2012 | 16 | 353 | 3,043 | 3,355 | 6,767 | ||||||||||||||||||||||
of which: | |||||||||||||||||||||||||||
developed | 16 | 402 | 6 | 424 | |||||||||||||||||||||||
undeveloped | 353 | 2,641 | 3,349 | 6,343 | |||||||||||||||||||||||
Purchase of minerals in place | |||||||||||||||||||||||||||
Revisions of previous estimates | 1 | (18 | ) | 16 | (2 | ) | (3 | ) | |||||||||||||||||||
Improved recovery | |||||||||||||||||||||||||||
Extensions and discoveries | |||||||||||||||||||||||||||
Production | (2 | ) | (5 | ) | (60 | ) | (67 | ) | |||||||||||||||||||
Sales of minerals in place | (2,971 | ) | (2,971 | ) | |||||||||||||||||||||||
Reserves at December 31, 2013 | 15 | 330 | 28 | 3,353 | 3,726 | ||||||||||||||||||||||
Reserves at December 31, 2013 | 1,532 | 1,247 | 5,246 | 2,704 | 1,957 | 772 | 3,862 | 848 | 18,168 | ||||||||||||||||||
Developed | 1,266 | 904 | 2,447 | 1,295 | 1,488 | 300 | 315 | 561 | 8,576 | ||||||||||||||||||
consolidated subsidiaries | 1,266 | 904 | 2,432 | 1,295 | 1,488 | 286 | 310 | 561 | 8,542 | ||||||||||||||||||
equity-accounted entities | 15 | 14 | 5 | 34 | |||||||||||||||||||||||
Undeveloped | 266 | 343 | 2,799 | 1,409 | 469 | 472 | 3,547 | 287 | 9,592 | ||||||||||||||||||
consolidated subsidiaries | 266 | 343 | 2,799 | 1,079 | 469 | 458 | 199 | 287 | 5,900 | ||||||||||||||||||
equity-accounted entities | 330 | 14 | 3,348 | 3,692 |
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Eni Fact Book Supplemental oil and gas information
Movements in net proved natural gas reserves | (bcf) |
Italy | Rest of Europe | North Africa | Sub-Saharan Africa | Kazakhstan | Rest of Asia | Americas | Australia and Oceania | Total | ||||||||||
2014 | |||||||||||||||||||||||||||
Consolidated subsidiaries | |||||||||||||||||||||||||||
Reserves at December 31, 2013 | 1,532 | 1,247 | 5,231 | 2,374 | 1,957 | 744 | 509 | 848 | 14,442 | ||||||||||||||||||
of which: | |||||||||||||||||||||||||||
developed | 1,266 | 904 | 2,432 | 1,295 | 1,488 | 286 | 310 | 561 | 8,542 | ||||||||||||||||||
undeveloped | 266 | 343 | 2,799 | 1,079 | 469 | 458 | 199 | 287 | 5,900 | ||||||||||||||||||
Purchase of minerals in place | 21 | ||||||||||||||||||||||||||
Revisions of previous estimates | 113 | 99 | 668 | 214 | 165 | 156 | 23 | (1 | ) | 1,437 | |||||||||||||||||
Improved recovery | |||||||||||||||||||||||||||
Extensions and discoveries | 19 | 341 | 59 | 16 | 435 | ||||||||||||||||||||||
Production | (213 | ) | (195 | ) | (627 | ) | (185 | ) | (73 | ) | (113 | ) | (80 | ) | (40 | ) | (1,526 | ) | |||||||||
Sales of minerals in place | (1 | ) | (1 | ) | |||||||||||||||||||||||
Reserves at December 31, 2014 | 1,432 | 1,171 | 5,291 | 2,744 | 2,049 | 846 | 468 | 807 | 14,808 | ||||||||||||||||||
Equity-accounted entities | |||||||||||||||||||||||||||
Reserves at December 31, 2013 | 15 | 330 | 28 | 3,353 | 3,726 | ||||||||||||||||||||||
of which: | |||||||||||||||||||||||||||
developed | 15 | 14 | 5 | 34 | |||||||||||||||||||||||
undeveloped | 330 | 14 | 3,348 | 3,692 | |||||||||||||||||||||||
Purchase of minerals in place | |||||||||||||||||||||||||||
Revisions of previous estimates | 2 | 25 | (2 | ) | 25 | ||||||||||||||||||||||
Improved recovery | |||||||||||||||||||||||||||
Extensions and discoveries | |||||||||||||||||||||||||||
Production | (2 | ) | (4 | ) | (8 | ) | (14 | ) | |||||||||||||||||||
Sales of minerals in place | |||||||||||||||||||||||||||
Reserves at December 31, 2014 | 15 | 351 | 18 | 3,353 | 3,737 | ||||||||||||||||||||||
Reserves at December 31, 2014 | 1,432 | 1,171 | 5,306 | 3,095 | 2,049 | 864 | 3,821 | 807 | 18,545 | ||||||||||||||||||
Developed | 1,192 | 887 | 2,125 | 1,360 | 1,553 | 271 | 399 | 675 | 8,462 | ||||||||||||||||||
consolidated subsidiaries | 1,192 | 887 | 2,110 | 1,271 | 1,553 | 261 | 393 | 675 | 8,342 | ||||||||||||||||||
equity-accounted entities | 15 | 89 | 10 | 6 | 120 | ||||||||||||||||||||||
Undeveloped | 240 | 284 | 3,181 | 1,735 | 496 | 593 | 3,422 | 132 | 10,083 | ||||||||||||||||||
consolidated subsidiaries | 240 | 284 | 3,181 | 1,473 | 496 | 585 | 75 | 132 | 6,466 | ||||||||||||||||||
equity-accounted entities | 262 | 8 | 3,347 | 3,617 |
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Eni Fact Book Supplemental oil and gas information
Results of operations from oil and gas producing activities | (euro million) |
Italy | Rest of Europe | North Africa | Sub-Saharan Africa | Kazakhstan | Rest of Asia | Americas | Australia and Oceania | Total | ||||||||||
2012 | |||||||||||||||||||||||||||
Consolidated subsidiaries | |||||||||||||||||||||||||||
Revenues: | |||||||||||||||||||||||||||
- sales to consolidated entities | 3,712 | 3,177 | 2,338 | 6,040 | 459 | 425 | 1,614 | 425 | 18,190 | ||||||||||||||||||
- sales to third parties | 50 | 715 | 9,129 | 2,243 | 1,368 | 1,387 | 106 | 333 | 15,331 | ||||||||||||||||||
Total revenues | 3,762 | 3,892 | 11,467 | 8,283 | 1,827 | 1,812 | 1,720 | 758 | 33,521 | ||||||||||||||||||
Operations costs | (302 | ) | (655 | ) | (606 | ) | (913 | ) | (188 | ) | (209 | ) | (361 | ) | (134 | ) | (3,368 | ) | |||||||||
Production taxes | (307 | ) | (390 | ) | (818 | ) | (43 | ) | (1,558 | ) | |||||||||||||||||
Exploration expenses | (32 | ) | (154 | ) | (153 | ) | (993 | ) | (3 | ) | (230 | ) | (147 | ) | (123 | ) | (1,835 | ) | |||||||||
D.D. & A. and provision for abandonment (a) | (777 | ) | (683 | ) | (1,137 | ) | (1,750 | ) | (120 | ) | (720 | ) | (1,256 | ) | (167 | ) | (6,610 | ) | |||||||||
Other income (expenses) | (201 | ) | (122 | ) | (934 | ) | (435 | ) | 206 | (149 | ) | 74 | (42 | ) | (1,603 | ) | |||||||||||
Pretax income from producing activities | 2,143 | 2,278 | 8,247 | 3,374 | 1,722 | 461 | 30 | 292 | 18,547 | ||||||||||||||||||
Income taxes | (919 | ) | (1,524 | ) | (5,194 | ) | (2,508 | ) | (736 | ) | (176 | ) | (14 | ) | (164 | ) | (11,235 | ) | |||||||||
Results of operations from E&P activities of consolidated subsidiaries (b) | 1,224 | 754 | 3,053 | 866 | 986 | 285 | 16 | 128 | 7,312 | ||||||||||||||||||
Equity-accounted entities | |||||||||||||||||||||||||||
Revenues: | |||||||||||||||||||||||||||
- sales to consolidated entities | |||||||||||||||||||||||||||
- sales to third parties | 2 | 20 | 44 | 144 | 300 | 510 | |||||||||||||||||||||
Total revenues | 2 | 20 | 44 | 144 | 300 | 510 | |||||||||||||||||||||
Operations costs | (10 | ) | (5 | ) | (14 | ) | (20 | ) | (49 | ) | |||||||||||||||||
Production taxes | (1 | ) | (3 | ) | (4 | ) | (128 | ) | (136 | ) | |||||||||||||||||
Exploration expenses | (5 | ) | (2 | ) | (11 | ) | (4 | ) | (22 | ) | |||||||||||||||||
D.D. & A. and provision for abandonment | (50 | ) | (2 | ) | (13 | ) | (41 | ) | (35 | ) | (141 | ) | |||||||||||||||
Other income (expenses) | (7 | ) | 2 | (48 | ) | (6 | ) | (55 | ) | (114 | ) | ||||||||||||||||
Pretax income from producing activities | (61 | ) | 5 | (33 | ) | 75 | 62 | 48 | |||||||||||||||||||
Income taxes | (3 | ) | 4 | (36 | ) | (38 | ) | (73 | ) | ||||||||||||||||||
Results of operations from E&P activities of equity-accounted entities (b) | (61 | ) | 2 | (29 | ) | 39 | 24 | (25 | ) |
(a) Includes asset impairments amounting to euro 547 million in 2012. (b) The "Successful Effort Method" application according to Eni accounting policy would have led to a decrease of result of operations of euro 610 million in 2012 for the consolidated subsidiaries and a decrease of euro 10 million in 2012 for equity-accounted entities. |
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Eni Fact Book Supplemental oil and gas information
Results of operations from oil and gas producing activities | (euro million) |
Italy | Rest of Europe | North Africa | Sub-Saharan Africa | Kazakhstan | Rest of Asia | Americas | Australia and Oceania | Total | ||||||||||
2013 | |||||||||||||||||||||||||||
Consolidated subsidiaries | |||||||||||||||||||||||||||
Revenues: | |||||||||||||||||||||||||||
- sales to consolidated entities | 3,784 | 2,468 | 2,341 | 5,264 | 396 | 870 | 1,537 | 146 | 16,806 | ||||||||||||||||||
- sales to third parties | 704 | 7,723 | 1,855 | 1,175 | 864 | 93 | 338 | 12,752 | |||||||||||||||||||
Total revenues | 3,784 | 3,172 | 10,064 | 7,119 | 1,571 | 1,734 | 1,630 | 484 | 29,558 | ||||||||||||||||||
Operations costs | (391 | ) | (717 | ) | (649 | ) | (932 | ) | (192 | ) | (224 | ) | (342 | ) | (119 | ) | (3,566 | ) | |||||||||
Production taxes | (326 | ) | (317 | ) | (710 | ) | (38 | ) | (25 | ) | (1,416 | ) | |||||||||||||||
Exploration expenses | (32 | ) | (288 | ) | (95 | ) | (869 | ) | (1 | ) | (205 | ) | (136 | ) | (110 | ) | (1,589 | ) | |||||||||
D.D. & A. and provision for abandonment (a) | (907 | ) | (573 | ) | (1,192 | ) | (1,882 | ) | (111 | ) | (524 | ) | (848 | ) | 43 | (5,994 | ) | ||||||||||
Other income (expenses) | (277 | ) | 161 | (1,009 | ) | (519 | ) | (105 | ) | (140 | ) | 20 | (11 | ) | (1,880 | ) | |||||||||||
Pretax income from producing activities | 1,851 | 1,755 | 6,802 | 2,207 | 1,162 | 603 | 324 | 262 | 14,966 | ||||||||||||||||||
Income taxes | (872 | ) | (1,006 | ) | (4,281 | ) | (1,702 | ) | (396 | ) | (178 | ) | (117 | ) | (149 | ) | (8,701 | ) | |||||||||
Results of operations from E&P activities of consolidated subsidiaries (b) | 979 | 749 | 2,521 | 505 | 766 | 425 | 207 | 113 | 6,265 | ||||||||||||||||||
Equity-accounted entities | |||||||||||||||||||||||||||
Revenues: | |||||||||||||||||||||||||||
- sales to consolidated entities | |||||||||||||||||||||||||||
- sales to third parties | 20 | 26 | 199 | 243 | 488 | ||||||||||||||||||||||
Total revenues | 20 | 26 | 199 | 243 | 488 | ||||||||||||||||||||||
Operations costs | (11 | ) | (44 | ) | (18 | ) | (23 | ) | (96 | ) | |||||||||||||||||
Production taxes | (4 | ) | (14 | ) | (113 | ) | (131 | ) | |||||||||||||||||||
Exploration expenses | (8 | ) | (3 | ) | (25 | ) | (1 | ) | (37 | ) | |||||||||||||||||
D.D. & A. and provision for abandonment | (1 | ) | (1 | ) | (65 | ) | (40 | ) | (107 | ) | |||||||||||||||||
Other income (expenses) | (4 | ) | 5 | (12 | ) | (13 | ) | (38 | ) | (62 | ) | ||||||||||||||||
Pretax income from producing activities | (13 | ) | 6 | (30 | ) | 64 | 28 | 55 | |||||||||||||||||||
Income taxes | (4 | ) | (10 | ) | (35 | ) | 30 | (19 | ) | ||||||||||||||||||
Results of operations from E&P activities of equity-accounted entities (b) | (13 | ) | 2 | (40 | ) | 29 | 58 | 36 |
(a) Includes asset impairments amounting to euro 15 million in 2013. (b) The "Successful Effort Method" application according to Eni accounting policy would have led to a decrease of result of operations of euro 295 million in 2013 for the consolidated subsidiaries and an increase of euro 6 million in 2013 for equity-accounted entities. |
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Eni Fact Book Supplemental oil and gas information
Results of operations from oil and gas producing activities | (euro million) |
Italy | Rest of Europe | North Africa | Sub-Saharan Africa | Kazakhstan | Rest of Asia | Americas | Australia and Oceania | Total | ||||||||||
2014 | |||||||||||||||||||||||||||
Consolidated subsidiaries | |||||||||||||||||||||||||||
Revenues: | |||||||||||||||||||||||||||
- sales to consolidated entities | 3,028 | 2,721 | 2,010 | 4,716 | 346 | 589 | 1,691 | 67 | 15,168 | ||||||||||||||||||
- sales to third parties | 596 | 7,415 | 1,369 | 976 | 774 | 129 | 299 | 11,558 | |||||||||||||||||||
Total revenues | 3,028 | 3,317 | 9,425 | 6,085 | 1,322 | 1,363 | 1,820 | 366 | 26,726 | ||||||||||||||||||
Operations costs | (423 | ) | (687 | ) | (694 | ) | (935 | ) | (208 | ) | (223 | ) | (357 | ) | (124 | ) | (3,651 | ) | |||||||||
Production taxes | (293 | ) | (291 | ) | (648 | ) | (33 | ) | (15 | ) | (1,280 | ) | |||||||||||||||
Exploration expenses | (29 | ) | (227 | ) | (207 | ) | (706 | ) | (185 | ) | (189 | ) | (46 | ) | (1,589 | ) | |||||||||||
D.D. & A. and provision for abandonment (a) | (818 | ) | (1,083 | ) | (1,288 | ) | (2,010 | ) | (91 | ) | (850 | ) | (1,181 | ) | (172 | ) | (7,493 | ) | |||||||||
Other income (expenses) | (184 | ) | (96 | ) | (773 | ) | (358 | ) | (251 | ) | (117 | ) | (78 | ) | (30 | ) | (1,887 | ) | |||||||||
Pretax income from producing activities | 1,281 | 1,224 | 6,172 | 1,428 | 772 | (45 | ) | 15 | (21 | ) | 10,826 | ||||||||||||||||
Income taxes | (351 | ) | (803 | ) | (3,928 | ) | (1,273 | ) | (291 | ) | (112 | ) | (6 | ) | (16 | ) | (6,780 | ) | |||||||||
Results of operations from E&P activities of consolidated subsidiaries (b) | 930 | 421 | 2,244 | 155 | 481 | (157 | ) | 9 | (37 | ) | 4,046 | ||||||||||||||||
Equity-accounted entities | |||||||||||||||||||||||||||
Revenues: | |||||||||||||||||||||||||||
- sales to consolidated entities | |||||||||||||||||||||||||||
- sales to third parties | 19 | 87 | 232 | 338 | |||||||||||||||||||||||
Total revenues | 19 | 87 | 232 | 338 | |||||||||||||||||||||||
Operations costs | (11 | ) | (11 | ) | (27 | ) | (49 | ) | |||||||||||||||||||
Production taxes | (3 | ) | (94 | ) | (97 | ) | |||||||||||||||||||||
Exploration expenses | (8 | ) | (45 | ) | (1 | ) | (54 | ) | |||||||||||||||||||
D.D. & A. and provision for abandonment | (1 | ) | (1 | ) | (44 | ) | (60 | ) | (106 | ) | |||||||||||||||||
Other income (expenses) | (1 | ) | 1 | (32 | ) | (3 | ) | (42 | ) | (77 | ) | ||||||||||||||||
Pretax income from producing activities | (10 | ) | 5 | (32 | ) | (16 | ) | 8 | (45 | ) | |||||||||||||||||
Income taxes | (4 | ) | (23 | ) | (17 | ) | (44 | ) | |||||||||||||||||||
Results of operations from E&P activities of equity-accounted entities (b) | (10 | ) | 1 | (32 | ) | (39 | ) | (9 | ) | (89 | ) |
(a) Includes asset impairments amounting to euro 690 million in 2014. (b) The "Successful Effort Method" application according to Eni accounting policy would have led to a decrease of result of operations of euro 5 million in 2014 for the consolidated subsidiaries and an increase of euro 24 million in 2014 for equity-accounted entities. |
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Eni Fact Book Supplemental oil and gas information
Capitalized cost (a) | (euro million) |
Italy | Rest of Europe | North Africa | Sub-Saharan Africa | Kazakhstan | Rest of Asia | Americas | Australia and Oceania | Total | ||||||||||
2013 | |||||||||||||||||||||||||||
Consolidated subsidiaries | |||||||||||||||||||||||||||
Proved mineral interests | 13,465 | 12,497 | 18,237 | 21,854 | 2,351 | 6,604 | 10,652 | 1,662 | 87,322 | ||||||||||||||||||
Unproved mineral interests | 31 | 385 | 428 | 2,835 | 37 | 1,441 | 1,419 | 190 | 6,766 | ||||||||||||||||||
Support equipment and facilities | 269 | 37 | 1,370 | 992 | 78 | 90 | 57 | 12 | 2,905 | ||||||||||||||||||
Incomplete wells and other | 799 | 2,803 | 1,105 | 1,851 | 6,069 | 634 | 669 | 24 | 13,954 | ||||||||||||||||||
Gross Capitalized Costs | 14,564 | 15,722 | 21,140 | 27,532 | 8,535 | 8,769 | 12,797 | 1,888 | 110,947 | ||||||||||||||||||
Accumulated depreciation, depletion and amortization | (10,241 | ) | (8,581 | ) | (11,370 | ) | (15,562 | ) | (1,000 | ) | (6,269 | ) | (8,406 | ) | (723 | ) | (62,152 | ) | |||||||||
Net Capitalized Costs consolidated subsidiaries (b) (c) | 4,323 | 7,141 | 9,770 | 11,970 | 7,535 | 2,500 | 4,391 | 1,165 | 48,795 | ||||||||||||||||||
Equity-accounted entities | |||||||||||||||||||||||||||
Proved mineral interests | 2 | 77 | 34 | 438 | 429 | 980 | |||||||||||||||||||||
Unproved mineral interests | 52 | 74 | 126 | ||||||||||||||||||||||||
Support equipment and facilities | 7 | 1 | 3 | 11 | |||||||||||||||||||||||
Incomplete wells and other | 20 | 4 | 1,059 | 378 | 1,461 | ||||||||||||||||||||||
Gross Capitalized Costs | 74 | 88 | 1,093 | 513 | 810 | 2,578 | |||||||||||||||||||||
Accumulated depreciation, depletion and amortization | (56 | ) | (67 | ) | (405 | ) | (145 | ) | (673 | ) | |||||||||||||||||
Net Capitalized Costs equity-accounted entities (b) (c) | 18 | 21 | 1,093 | 108 | 665 | 1,905 | |||||||||||||||||||||
2014 | |||||||||||||||||||||||||||
Consolidated subsidiaries | |||||||||||||||||||||||||||
Proved mineral interests | 14,862 | 13,754 | 21,549 | 27,697 | 2,917 | 8,827 | 13,050 | 1,825 | 104,481 | ||||||||||||||||||
Unproved mineral interests | 31 | 399 | 493 | 3,263 | 43 | 1,590 | 1,588 | 214 | 7,621 | ||||||||||||||||||
Support equipment and facilities | 346 | 42 | 1,569 | 1,164 | 94 | 35 | 66 | 13 | 3,329 | ||||||||||||||||||
Incomplete wells and other | 816 | 3,527 | 1,411 | 2,988 | 7,140 | 690 | 819 | 120 | 17,511 | ||||||||||||||||||
Gross Capitalized Costs | 16,055 | 17,722 | 25,022 | 35,112 | 10,194 | 11,142 | 15,523 | 2,172 | 132,942 | ||||||||||||||||||
Accumulated depreciation, depletion and amortization | (11,154 | ) | (9,519 | ) | (14,335 | ) | (20,039 | ) | (1,241 | ) | (8,042 | ) | (10,605 | ) | (1,009 | ) | (75,944 | ) | |||||||||
Net Capitalized Costs consolidated subsidiaries (b) (c) | 4,901 | 8,203 | 10,687 | 15,073 | 8,953 | 3,100 | 4,918 | 1,163 | 56,998 | ||||||||||||||||||
Equity-accounted entities | |||||||||||||||||||||||||||
Proved mineral interests | 2 | 77 | 24 | 539 | 549 | 1,191 | |||||||||||||||||||||
Unproved mineral interests | 31 | 84 | 115 | ||||||||||||||||||||||||
Support equipment and facilities | 7 | 1 | 4 | 12 | |||||||||||||||||||||||
Incomplete wells and other | 12 | 5 | 1,241 | 776 | 2,034 | ||||||||||||||||||||||
Gross Capitalized Costs | 45 | 89 | 1,265 | 624 | 1,329 | 3,352 | |||||||||||||||||||||
Accumulated depreciation, depletion and amortization | (39 | ) | (69 | ) | (522 | ) | (230 | ) | (860 | ) | |||||||||||||||||
Net Capitalized Costs equity-accounted entities (b) (c) | 6 | 20 | 1,265 | 102 | 1,099 | 2,492 |
(a) Capitalized costs represent the total expenditure for proved and unproved mineral interests and related support equipment and facilities utilized in oil and gas exploration and production activities, together with related accumulated depreciation, depletion and amortization. (b) The amounts include net capitalized financial charges totaling euro 715 million in 2013 and euro 868 million in 2014 for the consolidated subsidiaries and euro 12 million in 2013 and euro 46 million in 2014 for equity-accounted entities. (c) The amounts do not include costs associated with exploration activities which are capitalized in order to reflect their investment nature and amortized in full when incurred. The "Successful Effort Method" application according to Eni accounting policy would have led to an increase in net capitalized costs, mainly in relation to exploration cost, of euro 4,378 million in 2013 and euro 4,786 million in 2014 for the consolidated subsidiaries and euro 86 million in 2013 and euro 123 million in 2014 for equity-accounted entities. |
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Eni Fact Book Supplemental oil and gas information
Cost incurred (a) | (euro million) |
Italy | Rest of Europe | North Africa | Sub-Saharan Africa | Kazakhstan | Rest of Asia | Americas | Australia and Oceania | Total | ||||||||||
2012 | |||||||||||||||||||
Consolidated subsidiaries | |||||||||||||||||||
Proved property acquisitions | 14 | 27 | 2 | 43 | |||||||||||||||
Unproved property acquisitions | |||||||||||||||||||
Exploration | 32 | 151 | 153 | 1,142 | 3 | 193 | 80 | 96 | 1,850 | ||||||||||
Development (b) | 1,045 | 2,485 | 1,441 | 2,246 | 762 | 702 | 1,071 | 16 | 9,768 | ||||||||||
Total costs incurred consolidated subsidiaries | 1,077 | 2,636 | 1,608 | 3,415 | 765 | 895 | 1,153 | 112 | 11,661 | ||||||||||
Equity-accounted entities | |||||||||||||||||||
Proved property acquisitions | |||||||||||||||||||
Unproved property acquisitions | |||||||||||||||||||
Exploration | 13 | 2 | 11 | 4 | 30 | ||||||||||||||
Development (c) | 19 | 7 | 117 | 188 | 154 | 485 | |||||||||||||
Total costs incurred equity-accounted entities | 32 | 9 | 128 | 192 | 154 | 515 | |||||||||||||
2013 | |||||||||||||||||||
Consolidated subsidiaries | |||||||||||||||||||
Proved property acquisitions | 64 | 64 | |||||||||||||||||
Unproved property acquisitions | 45 | 45 | |||||||||||||||||
Exploration | 32 | 357 | 95 | 757 | 1 | 233 | 110 | 84 | 1,669 | ||||||||||
Development (b) | 697 | 1,855 | 765 | 2,617 | 600 | 719 | 1,141 | 57 | 8,451 | ||||||||||
Total costs incurred consolidated subsidiaries | 729 | 2,212 | 969 | 3,374 | 601 | 952 | 1,251 | 141 | 10,229 | ||||||||||
Equity-accounted entities | |||||||||||||||||||
Proved property acquisitions | |||||||||||||||||||
Unproved property acquisitions | |||||||||||||||||||
Exploration | 5 | 3 | 81 | 1 | 90 | ||||||||||||||
Development (c) | 1 | 5 | 39 | 353 | 318 | 716 | |||||||||||||
Total costs incurred equity-accounted entities | 6 | 8 | 39 | 434 | 319 | 806 | |||||||||||||
2014 | |||||||||||||||||||
Consolidated subsidiaries | |||||||||||||||||||
Proved property acquisitions | |||||||||||||||||||
Unproved property acquisitions | |||||||||||||||||||
Exploration | 29 | 188 | 227 | 635 | 160 | 139 | 20 | 1,398 | |||||||||||
Development (b) | 1,382 | 2,395 | 955 | 3,479 | 572 | 1,118 | 1,169 | 122 | 11,192 | ||||||||||
Total costs incurred consolidated subsidiaries | 1,411 | 2,583 | 1,182 | 4,114 | 572 | 1,278 | 1,308 | 142 | 12,590 | ||||||||||
Equity-accounted entities | |||||||||||||||||||
Proved property acquisitions | |||||||||||||||||||
Unproved property acquisitions | |||||||||||||||||||
Exploration | 2 | 33 | 1 | 36 | |||||||||||||||
Development (c) | 1 | 22 | 38 | 375 | 436 | ||||||||||||||
Total costs incurred equity-accounted entities | 2 | 1 | 22 | 71 | 376 | 472 |
(a) Cost incurred represent amounts both capitalized and expenses in connection with oil and gas producing activities. (b) Includes the abandonment costs of the assets for euro 1,381 million in 2012, negative for euro 191 million in 2013 and euro 2,062 million in 2014. (c) Includes the abandonment costs of the assets for euro 63 million in 2012, euro 10 million in 2013 and negative for euro 47 million in 2014. |
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Eni Fact Book Supplemental oil and gas information
Standardized measure of discounted future net cash flows
Estimated future cash
inflows represent the revenues that would be received
from production and are determined by applying the
year-end average prices during the years ended. Future price changes are considered only to the extent provided by contractual arrangements. Estimated future development and production costs are determined by estimating the expenditures to be incurred in developing and producing the proved reserves at the end of the year. Neither the effects of price and cost escalations nor expected future changes in technology and operating practices have been considered. The standardized measure is calculated as the excess of future cash inflows from proved reserves less future costs of producing and developing the reserves, future income taxes and a yearly 10% discount factor. Future production costs include the estimated expenditures related to the production of proved reserves plus any production taxes without consideration of future inflation. Future development costs include |
the estimated costs of
drilling development wells and installation of production
facilities, plus the net costs associated with
dismantlement and abandonment of wells and facilities,
under the assumption that year-end costs continue without
considering future inflation. Future income taxes were
calculated in accordance with the tax laws of the
countries in which Eni operates. The standardized measure of discounted future net cash flows, related to the preceding proved oil and gas reserves, is calculated in accordance with the requirements of FASB Extractive Activities - Oil & Gas (Topic 932). The standardized measure does not purport to reflect realizable values or fair market value of Enis proved reserves. An estimate of fair value would also take into account, among other things, hydrocarbon resources other than proved reserves, anticipated changes in future prices and costs and a discount factor representative of the risks inherent in the oil and gas exploration and production activity. |
- 97 -
Eni Fact Book Supplemental oil and gas information
Standardized measure of discounted future net cash flows | (euro million) |
Italy | Rest of Europe | North Africa | Sub-Saharan Africa | Kazakhstan | Rest of Asia | Americas | Australia and Oceania | Total | ||||||||||
December 31, 2012 | |||||||||||||||||||||||||||
Consolidated subsidiaries | |||||||||||||||||||||||||||
Future cash inflows | 30,308 | 38,912 | 108,343 | 56,978 | 53,504 | 7,881 | 11,008 | 4,957 | 311,891 | ||||||||||||||||||
Future production costs | (5,900 | ) | (8,190 | ) | (18,555 | ) | (14,844 | ) | (9,561 | ) | (2,854 | ) | (2,520 | ) | (921 | ) | (63,345 | ) | |||||||||
Future development and abandonment costs | (3,652 | ) | (7,511 | ) | (8,412 | ) | (6,873 | ) | (3,802 | ) | (1,974 | ) | (1,502 | ) | (197 | ) | (33,923 | ) | |||||||||
Future net inflow before income tax | 20,756 | 23,211 | 81,376 | 35,261 | 40,141 | 3,053 | 6,986 | 3,839 | 214,623 | ||||||||||||||||||
Future income tax | (6,911 | ) | (15,063 | ) | (44,256 | ) | (21,348 | ) | (10,293 | ) | (903 | ) | (2,906 | ) | (1,181 | ) | (102,861 | ) | |||||||||
Future net cash flows | 13,845 | 8,148 | 37,120 | 13,913 | 29,848 | 2,150 | 4,080 | 2,658 | 111,762 | ||||||||||||||||||
10% discount factor | (5,519 | ) | (2,630 | ) | (16,539 | ) | (4,976 | ) | (17,943 | ) | (496 | ) | (1,337 | ) | (1,030 | ) | (50,470 | ) | |||||||||
Standardized measure of discounted future net cash flows |
8,326 | 5,518 | 20,581 | 8,937 | 11,905 | 1,654 | 2,743 | 1,628 | 61,292 | ||||||||||||||||||
Equity-accounted entities | |||||||||||||||||||||||||||
Future cash inflows | 1 | 658 | 3,594 | 6,689 | 18,132 | 29,074 | |||||||||||||||||||||
Future production costs | (203 | ) | (576 | ) | (2,216 | ) | (5,003 | ) | (7,998 | ) | |||||||||||||||||
Future development and abandonment costs | (1 | ) | (17 | ) | (101 | ) | (1,061 | ) | (2,563 | ) | (3,743 | ) | |||||||||||||||
Future net inflow before income tax | 438 | 2,917 | 3,412 | 10,566 | 17,333 | ||||||||||||||||||||||
Future income tax | (36 | ) | (1,291 | ) | (795 | ) | (5,729 | ) | (7,851 | ) | |||||||||||||||||
Future net cash flows | 402 | 1,626 | 2,617 | 4,837 | 9,482 | ||||||||||||||||||||||
10% discount factor | (206 | ) | (962 | ) | (1,747 | ) | (3,621 | ) | (6,536 | ) | |||||||||||||||||
Standardized measure of discounted future net cash flows |
196 | 664 | 870 | 1,216 | 2,946 | ||||||||||||||||||||||
Total | 8,326 | 5,518 | 20,777 | 9,601 | 11,905 | 2,524 | 3,959 | 1,628 | 64,238 | ||||||||||||||||||
December 31, 2013 | |||||||||||||||||||||||||||
Consolidated subsidiaries | |||||||||||||||||||||||||||
Future cash inflows | 28,829 | 33,319 | 92,661 | 58,252 | 50,754 | 12,487 | 10,227 | 5,294 | 291,823 | ||||||||||||||||||
Future production costs | (6,250 | ) | (6,836 | ) | (16,611 | ) | (15,986 | ) | (9,072 | ) | (3,876 | ) | (2,379 | ) | (1,417 | ) | (62,427 | ) | |||||||||
Future development and abandonment costs | (4,593 | ) | (6,202 | ) | (8,083 | ) | (7,061 | ) | (3,445 | ) | (3,960 | ) | (1,561 | ) | (279 | ) | (35,184 | ) | |||||||||
Future net inflow before income tax | 17,986 | 20,281 | 67,967 | 35,205 | 38,237 | 4,651 | 6,287 | 3,598 | 194,212 | ||||||||||||||||||
Future income tax | (5,776 | ) | (12,746 | ) | (35,887 | ) | (20,491 | ) | (9,939 | ) | (1,391 | ) | (2,387 | ) | (1,093 | ) | (89,710 | ) | |||||||||
Future net cash flows | 12,210 | 7,535 | 32,080 | 14,714 | 28,298 | 3,260 | 3,900 | 2,505 | 104,502 | ||||||||||||||||||
10% discount factor | (5,048 | ) | (2,110 | ) | (14,327 | ) | (5,619 | ) | (16,984 | ) | (1,683 | ) | (1,353 | ) | (1,201 | ) | (48,325 | ) | |||||||||
Standardized measure of discounted future net cash flows |
7,162 | 5,425 | 17,753 | 9,095 | 11,314 | 1,577 | 2,547 | 1,304 | 56,177 | ||||||||||||||||||
Equity-accounted entities | |||||||||||||||||||||||||||
Future cash inflows | 524 | 4,041 | 262 | 17,239 | 22,066 | ||||||||||||||||||||||
Future production costs | (164 | ) | (1,465 | ) | (38 | ) | (5,467 | ) | (7,134 | ) | |||||||||||||||||
Future development and abandonment costs | (17 | ) | (85 | ) | (73 | ) | (2,299 | ) | (2,474 | ) | |||||||||||||||||
Future net inflow before income tax | 343 | 2,491 | 151 | 9,473 | 12,458 | ||||||||||||||||||||||
Future income tax | (20 | ) | (1,617 | ) | (61 | ) | (4,156 | ) | (5,854 | ) | |||||||||||||||||
Future net cash flows | 323 | 874 | 90 | 5,317 | 6,604 | ||||||||||||||||||||||
10% discount factor | (175 | ) | (401 | ) | (20 | ) | (3,681 | ) | (4,277 | ) | |||||||||||||||||
Standardized measure of discounted future net cash flows |
148 | 473 | 70 | 1,636 | 2,327 | ||||||||||||||||||||||
Total | 7,162 | 5,425 | 17,901 | 9,568 | 11,314 | 1,647 | 4,183 | 1,304 | 58,504 |
- 98 -
Eni Fact Book Supplemental oil and gas information
Standardized measure of discounted future net cash flows | (euro million) |
Italy | Rest of Europe | North Africa | Sub-Saharan Africa | Kazakhstan | Rest of Asia | Americas | Australia and Oceania | Total | ||||||||||
December 31, 2014 | |||||||||||||||||||||||||||
Consolidated subsidiaries | |||||||||||||||||||||||||||
Future cash inflows | 24,951 | 29,140 | 96,372 | 65,853 | 55,740 | 13,664 | 10,955 | 4,849 | 301,524 | ||||||||||||||||||
Future production costs | (6,374 | ) | (6,856 | ) | (19,906 | ) | (18,236 | ) | (9,878 | ) | (4,158 | ) | (2,680 | ) | (1,092 | ) | (69,180 | ) | |||||||||
Future development and abandonment costs | (4,698 | ) | (5,292 | ) | (9,673 | ) | (9,139 | ) | (4,576 | ) | (4,600 | ) | (1,892 | ) | (356 | ) | (40,226 | ) | |||||||||
Future net inflow before income tax | 13,879 | 16,992 | 66,793 | 38,478 | 41,286 | 4,906 | 6,383 | 3,401 | 192,118 | ||||||||||||||||||
Future income tax | (3,583 | ) | (10,595 | ) | (35,484 | ) | (20,514 | ) | (10,400 | ) | (1,462 | ) | (2,401 | ) | (989 | ) | (85,428 | ) | |||||||||
Future net cash flows | 10,296 | 6,397 | 31,309 | 17,964 | 30,886 | 3,444 | 3,982 | 2,412 | 106,690 | ||||||||||||||||||
10% discount factor | (4,064 | ) | (1,464 | ) | (13,905 | ) | (7,164 | ) | (19,699 | ) | (1,900 | ) | (1,353 | ) | (1,106 | ) | (50,655 | ) | |||||||||
Standardized measure of discounted future net cash flows |
6,232 | 4,933 | 17,404 | 10,800 | 11,187 | 1,544 | 2,629 | 1,306 | 56,035 | ||||||||||||||||||
Equity-accounted entities | |||||||||||||||||||||||||||
Future cash inflows | 485 | 3,861 | 200 | 18,871 | 23,417 | ||||||||||||||||||||||
Future production costs | (165 | ) | (692 | ) | (33 | ) | (5,724 | ) | (6,614 | ) | |||||||||||||||||
Future development and abandonment costs | (18 | ) | (104 | ) | (51 | ) | (2,032 | ) | (2,205 | ) | |||||||||||||||||
Future net inflow before income tax | 302 | 3,065 | 116 | 11,115 | 14,598 | ||||||||||||||||||||||
Future income tax | (23 | ) | (426 | ) | (45 | ) | (4,608 | ) | (5,102 | ) | |||||||||||||||||
Future net cash flows | 279 | 2,639 | 71 | 6,507 | 9,496 | ||||||||||||||||||||||
10% discount factor | (158 | ) | (1,442 | ) | (11 | ) | (4,327 | ) | (5,938 | ) | |||||||||||||||||
Standardized measure of discounted future net cash flows |
121 | 1,197 | 60 | 2,180 | 3,558 | ||||||||||||||||||||||
Total | 6,232 | 4,933 | 17,525 | 11,997 | 11,187 | 1,604 | 4,809 | 1,306 | 59,593 |
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Eni Fact Book Supplemental oil and gas information
Changes in standardized measure of discounted future net cash flows | (euro million) |
Consolidated subsidiaries | Equity-accounted entities | Total | ||||
Standardized measure of discounted future net cash flows at December 31, 2011 | 62,238 | 2,660 | 64,898 | ||||||
Increase (decrease): | |||||||||
- sales, net of production costs | (28,595 | ) | (325 | ) | (28,920 | ) | |||
- net changes in sales and transfer prices, net of production costs | 2,264 | (56 | ) | 2,208 | |||||
- extensions, discoveries and improved recovery, net of future production and development costs | 4,868 | 812 | 5,680 | ||||||
- changes in estimated future development and abandonment costs | (3,802 | ) | (357 | ) | (4,159 | ) | |||
- development costs incurred during the period that reduced future development costs | 8,199 | 409 | 8,608 | ||||||
- revisions of quantity estimates | 3,725 | 824 | 4,549 | ||||||
- accretion of discount | 12,527 | 477 | 13,004 | ||||||
- net change in income taxes | 2,207 | (830 | ) | 1,377 | |||||
- purchase of reserves in-place | |||||||||
- sale of reserves in-place | (1,509 | ) | (615 | ) | (2,124 | ) | |||
- changes in production rates (timing) and other | (830 | ) | (53 | ) | (883 | ) | |||
Net increase (decrease) | (946 | ) | 286 | (660 | ) | ||||
Standardized measure of discounted future net cash flows at December 31, 2012 | 61,292 | 2,946 | 64,238 | ||||||
Increase (decrease): | |||||||||
- sales, net of production costs | (24,576 | ) | (261 | ) | (24,837 | ) | |||
- net changes in sales and transfer prices, net of production costs | (3,632 | ) | (223 | ) | (3,855 | ) | |||
- extensions, discoveries and improved recovery, net of future production and development costs | 1,699 | 3 | 1,702 | ||||||
- changes in estimated future development and abandonment costs | (6,821 | ) | (427 | ) | (7,248 | ) | |||
- development costs incurred during the period that reduced future development costs | 8,456 | 665 | 9,121 | ||||||
- revisions of quantity estimates | 6,385 | (298 | ) | 6,087 | |||||
- accretion of discount | 11,937 | 521 | 12,458 | ||||||
- net change in income taxes | 5,587 | 379 | 5,966 | ||||||
- purchase of reserves in-place | 74 | 74 | |||||||
- sale of reserves in-place | (252 | ) | (770 | ) | (1,022 | ) | |||
- changes in production rates (timing) and other | (3,972 | ) | (208 | ) | (4,180 | ) | |||
Net increase (decrease) | (5,115 | ) | (619 | ) | (5,734 | ) | |||
Standardized measure of discounted future net cash flows at December 31, 2013 | 56,177 | 2,327 | 58,504 | ||||||
Increase (decrease): | |||||||||
- sales, net of production costs | (21,795 | ) | (192 | ) | (21,987 | ) | |||
- net changes in sales and transfer prices, net of production costs | (12,053 | ) | (500 | ) | (12,553 | ) | |||
- extensions, discoveries and improved recovery, net of future production and development costs | 1,667 | 1,667 | |||||||
- changes in estimated future development and abandonment costs | (6,047 | ) | 223 | (5,824 | ) | ||||
- development costs incurred during the period that reduced future development costs | 8,745 | 451 | 9,196 | ||||||
- revisions of quantity estimates | 8,085 | (325 | ) | 7,760 | |||||
- accretion of discount | 11,064 | 512 | 11,576 | ||||||
- net change in income taxes | 7,049 | 704 | 7,753 | ||||||
- purchase of reserves in-place | 67 | 67 | |||||||
- sale of reserves in-place | (271 | ) | (271 | ) | |||||
- changes in production rates (timing) and other | 3,347 | 358 | 3,705 | ||||||
Net increase (decrease) | (142 | ) | 1,231 | 1,089 | |||||
Standardized measure of discounted future net cash flows at December 31, 2014 | 56,035 | 3,558 | 59,593 |
- 100 -
Eni Fact Book Quarterly information
Quarterly information
Main financial data (a) (b) |
2012 | 2013 | 2014 | ||||
(euro million) | I quarter | II quarter | III quarter | IV quarter | I quarter | II quarter | III quarter | IV quarter | I quarter | II quarter | III quarter | IV quarter | |||||||||||||||||||||||||||||||||
Net sales from operations | 33,112 | 30,035 | 31,466 | 32,496 | 127,109 | 30,440 | 26,055 | 28,374 | 29,828 | 114,697 | 29,203 | 27,353 | 26,600 | 26,691 | 109,847 | ||||||||||||||||||||||||||||||
Operating income | 6,583 | 2,825 | 4,115 | 1,685 | 15,208 | 3,867 | 1,471 | 3,302 | 248 | 8,888 | 3,646 | 2,255 | 2,579 | (563 | ) | 7,917 | |||||||||||||||||||||||||||||
Adjusted operating profit: | 6,271 | 4,255 | 4,404 | 4,953 | 19,883 | 3,746 | 1,959 | 3,438 | 3,507 | 12,650 | 3,491 | 2,728 | 3,032 | 2,323 | 11,574 | ||||||||||||||||||||||||||||||
Exploration & Production | 5,095 | 4,239 | 4,336 | 4,867 | 18,537 | 3,998 | 3,409 | 3,916 | 3,320 | 14,643 | 3,450 | 2,981 | 3,088 | 2,032 | 11,551 | ||||||||||||||||||||||||||||||
Gas & Power | 1,042 | (378 | ) | (281 | ) | 15 | 398 | (211 | ) | (424 | ) | (344 | ) | 341 | (638 | ) | 241 | 70 | (109 | ) | 108 | 310 | |||||||||||||||||||||||
Refining & Marketing | (216 | ) | (134 | ) | 60 | 1 | (289 | ) | (134 | ) | (176 | ) | (55 | ) | (92 | ) | (457 | ) | (223 | ) | (219 | ) | 39 | 195 | (208 | ) | |||||||||||||||||||
Versalis | (169 | ) | (25 | ) | (173 | ) | (116 | ) | (483 | ) | (63 | ) | (82 | ) | (111 | ) | (130 | ) | (386 | ) | (89 | ) | (93 | ) | (98 | ) | (66 | ) | (346 | ) | |||||||||||||||
Engineering & Construction | 381 | 392 | 390 | 322 | 1,485 | 204 | (678 | ) | 220 | 155 | (99 | ) | 128 | 165 | 155 | 31 | 479 | ||||||||||||||||||||||||||||
Other activities | (45 | ) | (57 | ) | (40 | ) | (80 | ) | (222 | ) | (55 | ) | (52 | ) | (52 | ) | (51 | ) | (210 | ) | (45 | ) | (43 | ) | (42 | ) | (48 | ) | (178 | ) | |||||||||||||||
Corporate and financial companies | (80 | ) | (99 | ) | (64 | ) | (82 | ) | (325 | ) | (82 | ) | (76 | ) | (92 | ) | (82 | ) | (332 | ) | (81 | ) | (58 | ) | (65 | ) | (61 | ) | (265 | ) | |||||||||||||||
Unrealized profit intragroup elimination and consolidation adjustments | 263 | 317 | 176 | 26 | 782 | 89 | 38 | (44 | ) | 46 | 129 | 110 | (75 | ) | 64 | 132 | 231 | ||||||||||||||||||||||||||||
Net profit: (c) | 3,617 | 227 | 2,485 | 1,461 | 7,790 | 1,543 | 275 | 3,989 | (647 | ) | 5,160 | 1,303 | 658 | 1,714 | (2,384 | ) | 1,291 | ||||||||||||||||||||||||||||
- continuing operations | 3,544 | 156 | 2,464 | (1,964 | ) | 4,200 | 1,543 | 275 | 3,989 | (647 | ) | 5,160 | 1,303 | 658 | 1,714 | (2,384 | ) | 1,291 | |||||||||||||||||||||||||||
- discontinued operations | 73 | 71 | 21 | 3,425 | 3,590 | ||||||||||||||||||||||||||||||||||||||||
Capital expenditure | 2,643 | 3,026 | 3,235 | 3,901 | 12,805 | 3,122 | 2,825 | 3,064 | 3,789 | 12,800 | 2,545 | 2,979 | 3,083 | 3,633 | 12,240 | ||||||||||||||||||||||||||||||
Investments | 245 | 61 | 207 | 56 | 569 | 113 | 63 | 40 | 101 | 317 | 60 | 133 | 91 | 124 | 408 | ||||||||||||||||||||||||||||||
Net borrowings at period end | 26,984 | 26,467 | 19,175 | 15,069 | 15,069 | 15,519 | 15,984 | 14,687 | 14,963 | 14,963 | 13,799 | 14,601 | 15,837 | 13,685 | 13,685 |
(a) Quarterly data are unaudited. (b) In accordance with the guidelines of IFRS 5, results of the Italian regulated businesses managed by Snam divested in accordance to Law Decree No. 1/2012, enacted into Law on March 14, 2012 have been reported as discontinued operations from July 1, 2012. Prior year data have been reclassified accordingly. (c) Net profit attributable to Enis shareholders. |
Key market indicators |
2012 | 2013 | 2014 | ||||
I quarter | II quarter | III quarter | IV quarter | I quarter | II quarter | III quarter | IV quarter | I quarter | II quarter | III quarter | IV quarter | |||||||||||||||||||
Average price of Brent dated crude oil (a) | 118.49 | 108.19 | 109.61 | 110.02 | 111.58 | 112.60 | 102.44 | 110.37 | 109.27 | 108.66 | 108.20 | 109.63 | 101.85 | 76.27 | 98.99 | |||||||||||||||
Average EUR/USD exchange rate (b) | 1.311 | 1.281 | 1.250 | 1.297 | 1.285 | 1.321 | 1.306 | 1.324 | 1.361 | 1.328 | 1.370 | 1.371 | 1.325 | 1.249 | 1.329 | |||||||||||||||
Average price in euro of Brent dated crude oil | 90.38 | 84.46 | 87.69 | 84.33 | 86.83 | 85.24 | 78.44 | 83.36 | 80.29 | 81.82 | 78.98 | 79.96 | 76.87 | 61.06 | 74.48 | |||||||||||||||
Standard Eni Refining Margin (SERM) (c) | n.a. | n.a. | n.a. | n.a. | 4.12 | n.a. | 3.25 | 2.43 | 0.96 | 2.43 | 1.17 | 2.29 | 4.39 | 4.97 | 3.21 | |||||||||||||||
Price of NBP gas (d) | 9.34 | 9.09 | 9.00 | 10.49 | 9.48 | 11.46 | 10.06 | 10.11 | 10.93 | 10.63 | 9.95 | 7.55 | 7.03 | 8.37 | 8.22 | |||||||||||||||
Euribor - three-month euro rate (%) | 1.0 | 0.7 | 0.4 | 0.2 | 0.6 | 0.2 | 0.2 | 0.2 | 0.2 | 0.2 | 0.3 | 0.3 | 0.2 | 0.1 | 0.2 | |||||||||||||||
Libor - three-month dollar rate (%) | 0.5 | 0.5 | 0.4 | 0.3 | 0.4 | 0.3 | 0.3 | 0.3 | 0.2 | 0.3 | 0.2 | 0.2 | 0.2 | 0.2 | 0.2 |
(a) In USD per barrel. Source: Platts Oilgram. (b) Source: BCE. (c) In USD per barrel FOB Mediterranean Brent dated crude oil. Source: Eni calculations. Approximates the margin of Enis refining system in consideration of material balances and refineries product yields. (d) In USD per BTU (British Thermal Unit). Source Platts Oilgram. |
- 101 -
Eni Fact Book Quarterly information
Main operating data |
2012 | 2013 | 2014 | ||||
I quarter | II quarter | III quarter | IV quarter | I quarter | II quarter | III quarter | IV quarter | I quarter | II quarter | III quarter | IV quarter | |||||||||||||||||||
Liquids production | (kbbl/d) | 867 | 856 | 891 | 912 | 882 | 818 | 845 | 851 | 816 | 833 | 822 | 813 | 812 | 868 | 828 | ||||||||||||||||
Natural gas production | (mmcf/d) | 4,480 | 4,394 | 4,545 | 4,584 | 4,501 | 4,290 | 4,410 | 4,402 | 4,177 | 4,320 | 4,182 | 4,234 | 4,197 | 4,284 | 4,224 | ||||||||||||||||
Hydrocarbons production: | (kboe/d) | 1,683 | 1,656 | 1,718 | 1,747 | 1,701 | 1,600 | 1,648 | 1,653 | 1,577 | 1,619 | 1,583 | 1,584 | 1,576 | 1,648 | 1,598 | ||||||||||||||||
Italy | 188 | 187 | 187 | 195 | 189 | 180 | 181 | 189 | 192 | 186 | 182 | 179 | 174 | 182 | 179 | |||||||||||||||||
Rest of Europe | 206 | 173 | 162 | 172 | 178 | 158 | 151 | 141 | 173 | 155 | 192 | 195 | 179 | 196 | 190 | |||||||||||||||||
North Africa | 570 | 573 | 593 | 610 | 586 | 554 | 598 | 569 | 506 | 556 | 542 | 549 | 584 | 590 | 567 | |||||||||||||||||
Sub-Saharan Africa | 335 | 333 | 387 | 324 | 345 | 313 | 322 | 377 | 316 | 332 | 324 | 321 | 317 | 339 | 325 | |||||||||||||||||
Kazakhstan | 111 | 106 | 90 | 99 | 102 | 103 | 105 | 90 | 102 | 100 | 102 | 90 | 76 | 85 | 88 | |||||||||||||||||
Rest of Asia | 111 | 128 | 128 | 149 | 129 | 141 | 150 | 143 | 143 | 144 | 96 | 104 | 93 | 97 | 98 | |||||||||||||||||
Americas | 119 | 120 | 135 | 166 | 135 | 119 | 110 | 117 | 116 | 116 | 117 | 120 | 131 | 131 | 125 | |||||||||||||||||
Australia and Oceania | 43 | 36 | 36 | 32 | 37 | 32 | 31 | 27 | 29 | 30 | 28 | 26 | 22 | 28 | 26 | |||||||||||||||||
Production sold | (mmboe) | 149.2 | 144.6 | 150.5 | 154.4 | 598.7 | 135.8 | 140.3 | 141.8 | 137.4 | 555.3 | 134.7 | 133.0 | 138.5 | 143.3 | 549.5 | ||||||||||||||||
Sales of natural gas to third parties | (bcm) | 26.03 | 16.29 | 16.47 | 21.81 | 80.60 | 26.61 | 16.23 | 15.27 | 22.17 | 80.28 | 23.56 | 16.64 | 17.50 | 21.47 | 79.17 | ||||||||||||||||
Own consumption of natural gas | 1.77 | 1.57 | 1.58 | 1.51 | 6.43 | 1.56 | 1.29 | 1.53 | 1.55 | 5.93 | 1.48 | 1.27 | 1.44 | 1.43 | 5.62 | |||||||||||||||||
Sales to third parties and own consumption | 27.80 | 17.86 | 18.05 | 23.32 | 87.03 | 28.17 | 17.52 | 16.80 | 23.72 | 86.21 | 25.04 | 17.91 | 18.94 | 22.90 | 84.79 | |||||||||||||||||
Sales of natural gas of Eni's affiliates (net to Eni) | 2.81 | 2.29 | 1.43 | 1.76 | 8.29 | 2.00 | 1.57 | 1.55 | 1.84 | 6.96 | 1.72 | 1.18 | 0.68 | 0.80 | 4.38 | |||||||||||||||||
Total sales and own consumption of natural gas | 30.61 | 20.15 | 19.48 | 25.08 | 95.32 | 30.17 | 19.09 | 18.35 | 25.56 | 93.17 | 26.76 | 19.09 | 19.62 | 23.70 | 89.17 | |||||||||||||||||
Electricity sales | (TWh) | 12.29 | 9.62 | 10.54 | 10.13 | 42.58 | 9.16 | 8.69 | 8.45 | 8.75 | 35.05 | 8.25 | 7.75 | 8.26 | 9.32 | 33.58 | ||||||||||||||||
Sales of refined products: | (mmtonnes) | 10.01 | 12.73 | 13.25 | 12.34 | 48.33 | 10.65 | 10.42 | 11.91 | 10.51 | 43.49 | 10.32 | 11.03 | 11.41 | 11.65 | 44.41 | ||||||||||||||||
Retail sales in Italy | 1.81 | 1.98 | 2.24 | 1.80 | 7.83 | 1.65 | 1.71 | 1.71 | 1.57 | 6.64 | 1.45 | 1.60 | 1.58 | 1.51 | 6.14 | |||||||||||||||||
Wholesale sales in Italy | 2.06 | 2.18 | 2.20 | 2.18 | 8.62 | 1.86 | 2.08 | 2.26 | 2.17 | 8.37 | 1.68 | 1.79 | 2.12 | 1.98 | 7.57 | |||||||||||||||||
Retail sales Rest of Europe | 0.72 | 0.76 | 0.81 | 0.75 | 3.04 | 0.68 | 0.78 | 0.83 | 0.76 | 3.05 | 0.71 | 0.78 | 0.83 | 0.75 | 3.07 | |||||||||||||||||
Wholesale sales Rest of Europe | 0.89 | 1.03 | 1.05 | 0.99 | 3.96 | 0.94 | 1.08 | 1.10 | 1.11 | 4.23 | 1.01 | 1.17 | 1.23 | 1.19 | 4.60 | |||||||||||||||||
Wholesale sales outside Europe | 0.10 | 0.11 | 0.10 | 0.11 | 0.42 | 0.10 | 0.11 | 0.11 | 0.11 | 0.43 | 0.10 | 0.11 | 0.11 | 0.11 | 0.43 | |||||||||||||||||
Other markets | 4.43 | 6.67 | 6.85 | 6.51 | 24.46 | 5.42 | 4.66 | 5.90 | 4.79 | 20.77 | 5.37 | 5.58 | 5.54 | 6.11 | 22.60 |
- 102 -
This
summary review comprises an extract of the description of
the businesses, the managements discussion and
analysis of financial condition and results of operations
and certain other Company information from Enis
Integrated Annual Report for the year ended December 31,
2014. It does not contain sufficient information to allow
as full an understanding of financial results, operating
performance and business developments of Eni as "Eni
2014 Integrated Annual Report". It is not deemed to
be filed or submitted with any Italian or US market or
other regulatory authorities. You may obtain a copy of
"Summary Annual Review - Eni in 2014" and
"Eni 2014 Integrated Annual Report" on request,
free of charge (see the request form on Enis
website eni.com under the section
"Publications"). The "Summary Annual Review" and "Eni 2014 Integrated Annual Report" may be downloaded from Enis web site under the section "Publications". Financial data presented in this report is based on Consolidated Financial Statements prepared in accordance with the IFRS endorsed by the EU. This report contains certain forward-looking statements particularly those regarding capital expenditure, development and management of oil&gas resources, dividends, buy-back, allocation of future cash flow from operations, future operating performance, gearing, targets of production and sale growth, new markets and the progress and timing of projects. By their nature, forward-looking statements involve risks and uncertainties because they relate to events and depend on circumstances that will or may occur in the future. Actual results may differ from those expressed in such statements, depending on a variety of factors, including the timing of bringing new fields on stream; managements ability in carrying out industrial plans and in succeeding in commercial transactions; future levels of industry product supply; demand and pricing; operational problems; general economic conditions; political stability and economic growth in relevant areas of the world; changes in laws and regulations; development and use of new technologies; changes in public expectations and other changes in business conditions; the actions of competitors and other factors discussed elsewhere in this document. As Eni shares, in the form of ADRs, are listed on the New York Stock Exchange (NYSE), an Annual Report on Form 20-F has been filed with the US Securities and Exchange Commission in accordance with the US Securities Exchange Act of 1934. Hard copies may be obtained free of charge (see the request form on Enis website eni.com under the section "Publications"). Eni discloses on its Annual Report on Form 20-F significant ways in which its corporate governance practices differ from those mandated for US companies under NYSE listing standards. The term "shareholder" in this report means, unless the context otherwise requires, investors in the equity capital of Eni SpA, both direct and/or indirect. Eni shares are traded on the Italian Stock Exchange (Mercato Telematico Azionario) and on the New York Stock Exchange (NYSE) under the ticker symbol "E". |
n | Eni at a glance Our business model Our strategy Business review |
2 4 6 |
|
n | n Exploration & Production n Gas & Power n Refining & Marketing n Versalis n Engineering & Construction Financial review |
8 12 14 16 18 |
||
n | Group results for the year 2014 results Profit and loss account Summarized Group balance sheet Summarized Group cash flow statements |
20 20 23 28 30 |
||
n | Directors and officers Investor information |
34 38 |
Eni at a glance Eni in 2014
- 2 -
Eni at a glance Eni in 2014
- 3 -
Our business model Eni in 2014
Our business model
Enis business model targets the delivery of long-term value to its stakeholders. This will leverage on profitable production growth, restructuring the mid-downstream businesses, efficiency and operational excellence and managing the operational risks. Our business model is underpinned by our relentless focus on capital stewardship, environmental conservation, attention to local communities, preservation of health and safety of people working in Eni and with Eni, respect of human rights and endorsement of ethics and transparency. The main capitals used by Eni (financial capital, productive capital, intellectual capital, natural capital, human capital, | social and relationship
capital) are classified in accordance with the criteria
included in the "International IR Framework"
published by the International Integrated Reporting
Council (IIRC). 2014 financial results and sustainability
performance rely on the responsible and efficient use of
our capitals. Hereunder is articulated the map of the main capitals exploited by Eni and actions positively effecting on their quality and availability. At the same time, the scheme evidences how the efficient use of capitals and related connections create value for the Company and its stakeholders. |
- 4 -
- 5 -
Our strategy Eni in 2014
Our strategy
In order to manage a
radically changed price environment, the Company outlined
for the next four-year period an action plan which
comprises a number of rigorous initiatives and objectives
in order to mitigate the impact of lower oil prices and
to preserve a robust financial structure, particularly in
the short to medium term. Our oil price assumptions for
the Brent benchmark are $55 per barrel in 2015 and we
expect a gradual recovery in the subsequent years up to
our long-term case of $90 per barrel. Against the
backdrop of a low price environment in the short to
medium term, our primary target remains cash generation
which will be underpinned by well-designed industrial
actions, capital discipline, focus on Exploration &
Production activities and a large disposal plan. In
approving the capital expenditure plan the Company
selected high-return projects with short pay-back
periods; this optimization will result in a euro 48
billion capital expenditures in the next four years, down
by approximately 17% compared to the previous plan, net
of exchange rate effects. The disposal plan, amounting to
more than euro 8 billion in the 2015-2018 period, is
based on the anticipated monetization of exploratory
discoveries, optimization of the upstream portfolio,
rationalization of midstream and downstream portfolio,
and the divestment of residual interests in Snam and
Galp. The Company forecasts that the planned industrial
actions, the selective approach to capital expenditure
and the disposal plan will enable Eni to preserve a
robust financial structure and we plan to maintain the
leverage below the threshold of 0.30 throughout the oil
cycle. As part of its effort to preserve liquidity and
the balance sheet, the Company decided to rebase the
dividend as it is planning to pay a dividend of euro 0.8
per share for fiscal year 2015. In the subsequent years, management will reassess its progressive dividend policy against the backdrop of an expected improvement in the oil price scenario and the planned growth in our cash generation as our value-generation strategy in Exploration & Production and our turnaround of Gas & Power, Refining & Marketing and Versalis progress on targets. |
The planned reduction in capital expenditure, which
will foresee a 17% reduction versus the previous plan at
constant exchange rate assumptions, will leverage on: In conclusion, the strategic transformation we started last May aims at making Eni more focused on exploration and production activities and more profitable by streamling the organization, turning around loss-making segments and diluting our presence in non-core activities. |
- 6 -
- 7 -
Exploration & Production / Business review Eni in 2014
Key performance indicators | |||
2012 | 2013 | 2014 |
Injury frequency rate of total Eni workforce | (No. of accidents per million of worked hours) | 0.34 | 0.23 | 0.23 | |||||
Net sales from operations (a) | (euro million) | 35,874 | 31,264 | 28,488 | |||||
Operating profit | 18,470 | 14,868 | 10,766 | ||||||
Adjusted operating profit | 18,537 | 14,643 | 11,551 | ||||||
Adjusted net profit | 7,426 | 5,950 | 4,423 | ||||||
Capital expenditure | 10,307 | 10,475 | 10,524 | ||||||
Adjusted ROACE | (%) | 17.6 | 13.5 | 9.5 | |||||
Profit per boe (b) | ($/boe) | 16.0 | 15.5 | 9.9 | |||||
Opex per boe (b) | 7.1 | 8.3 | 8.4 | ||||||
Cash Flow per boe (d) | 32.8 | 31.9 | 30.1 | ||||||
Finding & Development cost per boe (c) (d) | 17.4 | 19.2 | 21.5 | ||||||
Average hydrocarbons realizations (d) | 73.39 | 71.87 | 65.49 | ||||||
Production of hydrocarbons (d) | (kboe/d) | 1,701 | 1,619 | 1,598 | |||||
Estimated net proved reserves of hydrocarbons (d) | (mmboe) | 7,166 | 6,535 | 6,602 | |||||
Reserves life index (d) | (years) | 11.5 | 11.1 | 11.3 | |||||
Organic reserves replacement ratio (d) | (%) | 147 | 105 | 112 | |||||
Employees at year end | (number) | 11,304 | 12,352 | 12,777 | |||||
of which: outside Italy | 7,371 | 8,219 | 8,243 | ||||||
Oil spills due to operations (>1 barrel) | (bbl) | 3,015 | 1,728 | 936 | |||||
Produced water re-injected | (%) | 49 | 55 | 56 | |||||
Direct GHG emissions | (mmtonnes CO2 eq) | 28.68 | 25.90 | 22.98 | |||||
of which: from flaring | 9.46 | 8.48 | 5.64 | ||||||
Community investment | (euro million) | 59 | 53 | 63 | |||||
(a) Before elimination of intragroup sales. (b) Consolidated subsidiaries. (c) Three-year average. (d) Includes Enis share of equity-accounted entities. |
2014 |
Highlights |
|
Performance of the year è 2014 marked our strong focusing in HSE activities with significant improvements in all KPIs: - the injury frequency rate confirmed the positive 2013 performance; - greenhouse gas emissions decreased by 11.3% (down by 33.5% from flaring); - oil spills due to operations decreased by 46%; - zero blow-outs for the eleventh consecutive year; and - water re-injection reported a new record at 56% of water reused in operations. è Adjusted net profit declined by euro 1,527 million, or 25.7%, due to lower crude oil and gas prices in dollar terms (down |
by 8.9% on average)
reflecting a falling Brent crude benchmark and a weak gas
market, especially in Europe. è Oil and natural gas production was 1.598 million boe/d in 2014 (up by 0.6% compared to the previous year), excluding the impact of the divestment of Enis interest in Siberian assets. è Estimated net proved reserves at December 31, 2014 amounted to 6.6 bboe based on a reference Brent price of $101 per barrel. The reserves replacement ratio was 112%. The reserves life index was 11.3 years (11.1 years in 2013). è Development expenditure was euro 9,021 million (up by 5.1% from 2013) to |
progress major projects and
to maintain production plateau particularly in Norway,
Angola, Congo, the United States, Italy, Nigeria, Egypt,
Indonesia and Kazakhstan. è Eni continued its track record of exploratory success. Additions to the Companys resource backlog were approximately 900 million boe, at a competitive cost of $2.1 per barrel. Exploration and development
activities |
- 8 -
and the utilization of
existing production infrastructures: - Ochigufu in the Angolan deep waters of Block 15/06 (Eni operator with a 35% interest) with a potential in place estimated at approximately 300 million barrels of oil; - Minsala in the conventional waters of Block Marine XII (Eni operator with a 65% interest) in Congo, increasing the blocks resources in place by 1 billion barrels; - Oglan in Block 10 (Eni operator with a 100% interest) in Ecuador, with a potential in place estimated at approximately 300 million barrels of oil; - Merakes in East Sepinggan offshore block (Eni operator with a 85% interest) in Indonesia, with a potential of gas in place estimated at approximately 2 Tcf; |
- Nyonie in Block D4 (Eni
operator with a 100% interest) in the conventional waters
of Gabon, showed an estimated potential of approximately
500 million boe in place of gas and condensates; and - the appraisal wells at the Agulha and Coral gas discoveries in Mozambique confirmed reach and extension of their respective reservoirs with a potential in place in Area 4 (Eni operator with a 50% interest) estimated at approximately 88 Tcf. è Our acreage was strengthened by adding 100,000 square kilometers net to Eni, which puts us in a position to restart a new exploration cycle. Main licenses were located in high potential areas such as Myanmar, Portugal, South Africa and Vietnam, as well as legacy areas such as Algeria, China, |
Egypt, Norway, the United
Kingdom and the United States. è The West Hub Development Project in Block 15/06 achieved the first oil late in 2014. This is the first Eni-operated project in Angola, with production ramp-up expected to reach a plateau of up to 100 kbbl/d in the coming months. è Production start-up achieved at the recent Nené discovery in Block Marine XII in Congo. The full-field development will take place in several stages, with a plateau of over 120 kbbl/d. è Sanctioned the integrated oil&gas project of the Offshore Cape Three Points (Eni operator with a 47.22% interest) in Ghana. First oil is expected in 2017, first gas in 2018 and production is expected to peak at 80 kboe/d. |
|
Strategies Our upstream growth model
will continue to focus on the organic development of
conventional assets, with large resource base and
competitive cost structure. Those features will safeguard
the profitability of our oil&gas projects even in a
low price environment. In the next four years, against the backdrop of weak
crude oil prices, we intend to monetize our resources by: We plan to grow production at an average rate of 3.5% over the next four years, leveraging on a robust pipeline of projects with an average break-even of $45 per boe, which together with the ramp-ups at fields started up in 2014 will add more than 650 kboe/d in 2018. This new production will bring an additional cumulative cash flow of euro 19 billion in the 2015-2018 plan periods. The main planned start-ups are the Goliat field (Eni operator with a 65% interest) in the Barents Sea in Norway, the oil&gas project of Offshore Cape Three Points (Eni operator with a 47.22% interest) in Ghana, the Jangkrik project (Eni operator with a 55% interest) in Indonesia and production re-start of Kashagan field |
(Enis interest 16.81%)
by the end of 2016. The profitability of these projects
will be ensured by tight control on execution and
time-to-market leveraging on our new development approach
whereby we insourced critical project phases. To cope
with falling oil prices we plan to be selective in our
capital allocation decisions. In 2015-2018 plan periods,
we expect a decrease of approximately 13% of capital
expenditure net of exchange rate effects versus the
previous four-year plan due to a reduction in exploration
expenditures which will be focused on near-field and
appraisal activities, the re-phasing certain projects yet
to be sanctioned, as well as we plan to achieve cost
savings by renegotiating contracts for the supply of
oilfield services, equipment and other upstream goods. Finally, we intend to manage the typical upstream risks. A major part of our activities are currently located in countries that are far from high-risk areas and Eni plans to growth mainly in countries with low-mid political risk (approximately 90% of the capital expenditure of the four-year plan). We plan to control the environmental risk by means of strict selection of contractors, and by retaining operatorship in a large number of projects (84% of production related to start-ups). Execution of drilling activities at high pressure/high temperature wells and deep waters wells (24% of planned wells to be drilled in 2015) will be managed by continually deploying our high operational standards. | Maintaining strong production growth Enis Exploration & Production segment engages in oil and natural gas exploration and field development and production, as well as LNG operations, in 40 countries, including Italy, Libya, Egypt, Norway, the United Kingdom, Angola, Congo, Nigeria, the United States, Kazakhstan, Algeria, Australia, Venezuela, Iraq, Ghana and Mozambique. |
- 9 -
Exploration & Production / Business review Eni in 2014
We are targeting a
production rate of 3.5% in the next four-year plan.
Management plans to achieve the target production growth
by continuing development activities and new project
start-ups in the main areas of operations, including
North Africa, Sub-Saharan Africa, Barents Sea,
Kazakhstan, Venezuela and the Far East, leveraging
Enis vast knowledge of reservoirs and geological
basins, as well as technical and producing synergies. Management plans to maximize the production recovery rate at our current fields by counteracting natural field depletion and reducing facilities downtime. This will require intense development activities of work-over and infilling and careful planning of maintenance activities. We expect that continuing technological innovation and competence build-up will drive increasing rates of reserve recovery. Management intends to implement a number of initiatives to support profitability in its upstream operations by exercising tight control on project time schedules and costs. We plan to achieve efficient development of our reserves by: (i) in-sourcing critical engineering and project management activities also redeploying to other areas key competences which will be freed with the start-up of certain strategic projects and increase direct control and governance on construction and commissioning activities; and (ii) signing framework agreements with major suppliers, using standardized specifications to speed up pre-award process for critical equipment and plants, increasing focus on supply chain programming to optimize order flows. Based on these initiatives we believe that almost all of our project which we are currently developing over the next four-year plan will be completed on time and on cost schedule. Production
and reserves: 2014 and outlook |
the timing of individual
project start-ups, operational outages, reservoir
performance, regulatory changes, asset sales, severe
weather events, price effects under production sharing
contracts and other factors. Estimated net proved reserves at December 31, 2014 amounted to 6.6 bboe based on a reference Brent price of $101 per barrel. Additions to proved reserves booked in 2014 were 654 mmboe and derived from: (i) revisions of previous estimates were 524 mmboe mainly reported in Libya, Italy, Kazakhstan and Congo due to contractual revisions, continuous development activities and field performances; (ii) extensions and discoveries were up by 124 mmboe, with major increases booked in Ghana, Indonesia, the United States and Congo following new project sanctions and proved area extensions; (iii) improved recovery were up by 6 mmboe mainly reported in Algeria and Kazakhstan; (iv) sales of mineral-in-place mainly related to the divestment of assets in Nigeria (down by 7 mmboe) and the United Kingdom (down by 1 mmboe); and (v) purchases of minerals-in-place referred mainly to interests in assets located in the United Kingdom (up by 4 mmboe). The reserves life index was 11.3 years (11.1 years in 2013). Eni intends to pay special attention to reserve replacement in order to ensure the medium to long-term sustainability of the business. In 2014, we achieved an all sources replacement ratio of 112% through fast sanctioning and relentless focus on field development. Going forward, our reserve replacement will be underpinned by our strong focus on exploration and timely conversion of resources into reserves and production, while at the same time fighting depletion and enhancing the recovery factor in existing fields through effective reservoir management. | Exploration Exploration is the engine of our strategy in the upstream business. Exploration has proved to be a driver of production growth and value generation, as well as Enis distinctive feature among the oil majors. Since 2008, Eni has discovered over 10 billion boe in place, corresponding to a growth of 35% in our resource base, more than every other player in the oil industry, of which approximately 900 million boe were discovered in 2014, at a competitive cost of $2.1 per boe. Near-field discoveries marked the years activity, in particular: (i) Ochigufu in the deep waters of Block 15/06 in Angola; (ii) in the conventional waters of Block Marine XII in Congo, Minsala was the third discovery in the last two years increasing the blocks resources in place by 1 billion barrels with characteristics similar to the previous discoveries of Litchendjili and Nené, the latter started up early production in record time; (iii) Oglan in Block 10 in Ecuador with a potential in place estimated at approximately 300 million barrels of oil located near the processing facilities of the operated field of Villano; (iv) Merakes in offshore Indonesia. This discovery with a potential in place estimated at approximately 2 Tcf, is located in proximity of the operated field of Jangkrik, which is currently under development and will supply additional gas volumes to the Bontang LNG plant; (v) the appraisal gas wells Agulha 2 and Coral 4 DIR in Mozambique, confirming the extension of their respective fields with a potential in place in Area 4 estimated at approximately 88 Tcf; (vi) Nyonie in the conventional waters of |
- 10 -
Exploration & Production / Business review Eni in 2014
Block D4 in Gabon, with an
estimated potential of approximately 500 million boe in
place of gas and condensates; (vii) the oil&gas
Drivis discovery made at the offshore license PL 532 (Eni
30%) in Norway, with volumes in place estimated in the
range of 125 and 140 million barrels and will be put into
production with the development of the Johan Castberg
Hub; and (viii) the oil discovery ARM-14 in the Abu
Rudeis license (Eni 100%) in the Gulf of Suez in Egypt,
doubled production level in 2014. These discoveries are
expected to have a rapid time-to-market leveraging on the
synergies from the front-end loading of ongoing projects
and utilization of existing production infrastructures. Leveraging on these results, our exploration plan has been shaped to face the actual challenging scenario: by shifting focus to proven plays and near field exploration where we plan to drill 70% of our scheduled wells; and by reducing capital expenditure of 35% net of exchange rate effects in 2015 and 25% over the plan period. Exploration projects will attract some euro 5 billion. The most important amounts of exploration expenses will be incurred in Norway, Nigeria, the United States and Italy. We target the discovery of 2 billion boe of new resources in the four-year plan at a very competitive cost of $2.6 per boe. We plan to anticipate cash generation by disposal of interests in our discoveries in order to balance costs/risk exposure and profitability in an optimal way, in the meanwhile ensuring the reserve replacement and balanced presence in the worldwide upstream. We plan to mitigate the operational risk relating to drilling activities by applying Enis rigorous procedures throughout the engineering and execution stages by leveraging on proprietary drilling technologies, excellent skills and know-how, increased control of operations and by deploying technologies which we believe to be able to reduce blow-out risks and to enable the Company to respond quickly and effectively in case of emergencies. We renewed our exploration portfolio through the acquisition of new acreage covering approximately 100,000 square kilometers net to Eni, along the guideline of diversifying the geographical presence. As of December 31, 2014, Enis mineral right portfolio consisted of 938 exclusive or shared rights of exploration and development activities for a total acreage of 334,739 square kilometers net to Eni of which developed acreage of 40,771 square kilometers and undeveloped acreage of 293,968 square kilometers net to Eni. We confirm our expansion plans in the Pacific Basin, where we signed the contracts of production sharing for the exploration of 2 onshore blocks in Myanmar and 3 offshore blocks in Vietnam, in addition to the acquisition of licenses in Indonesia, Australia and China. We also confirm our interest for the unexplored basins, following Enis entrance in the offshore of Portugal, South Africa and deep offshore of Egypt. | Develop new projects to fuel future growth Eni has a strong pipeline of development projects that will fuel the medium and long-term growth of its oil and gas production. The pipeline of projects is geographically diversified and will become even more balanced across our hubs. These projects have an average breakeven of $45 per boe and will generate an overall cash |
flow from operations of euro
19 billion in the four-year plan. We are aiming at excellence in time-to-market in order to maximize the value of our reserves. We plan to achieve development efficiency leveraging on the integration of skills along the life cycle of the reserves and by deploying an innovative organizational model which insources engineering and retains tight control of construction and commissioning. Phased project development allowed us to mitigate operating risks and reduce the financial exposure. This approach led to the top results in the industry such as, above mentioned, the West Hub Development Project in Angola and the Block Marine XII in Congo. The latter is the best example of our integrated approach. With the discoveries of Nené, Minsala and Litchendjili we proved that, with advanced technology and innovative geological concepts, it is feasible to unlock material upside also in mature acreage. The huge potential of this play is now about 5.5 bboe of resources and we expect further upsides from the completion of the appraisal of Minsala and the drilling of two additional prospects. In Nené, we expect FID for the second phase by the end of 2015. In addition, later this year, Litchendjili will start oil&gas production. At the end of this decade, we will achieve an overall production of 150 kboe/d. In the next four years, we plan to start-up 16 new major fields operated by Eni. In addition to the above mentioned fields, the main projects include: (i) the Goliat field in the Barents Sea in Norway. The FPSO vessel reached Norway in April 2015 and started the final commissioning phase. Start-up is expected in the second half of 2015, with a production plateau at approximately 65 kboe/d net to Eni in 2016; (ii) the giant Perla gas field in the Block Cardon IV (Enis interest 50%), located in the Gulf of Venezuela. The early production start-up is expected by the second quarter of 2015 with a target production of approximately 460 mmcf/d. Production ramp-up is expected in 2017 with a target of approximately 800 mmcf/d. The development plan targets a long-term production plateau of approximately 1,200 mmcf/d in 2020; (iii) the East Hub in Block 15/06 in Angola, which will leverage on the synergies with West Hub. Production start-up is expected in 2017, contributing to an overall block production of 45 kboe/d at the end of the period; (iv) the Offshore Cape Three Points block in Ghana, with a fast track deep offshore development and time-to-market of just four years. Management plans to sanction FID in December and production start-up is targeted in 2017. The project will reach a production of about 40 kboe/d in 2019; and (v) the Jangkrik field in the Kalimantan offshore, in Indonesia. The project includes drilling of production wells linked to a Floating Production Unit for gas and condensate treatment, as well as construction of a transportation facility. Start-up is expected in 2017. Finally we plan to achieve further cost efficiencies by: (i) increasing the scale of our operations as we concentrate our resources on larger fields than in the past where we plan to achieve economies of scale; (ii) expanding projects where we serve as operator. We believe operatorship will enable the Company to exercise better cost control, effectively manage reservoir and production operations, and deploy our safety standards and procedures to minimize risks; (iii) applying our technologies which we believe can reduce drilling and completion costs; and (iv) renegotiating contracts for oilfield services and other items to reap the benefits of the deflationary trend in the industry. |
- 11 -
Gas & Power / Business review Eni in 2014
Key performance indicators | |||
2012 | 2013 | 2014 |
Injury frequency rate of total Eni workforce | (No. of accidents per million of worked hours) | 2.23 | 1.43 | 0.49 | |||||
Net sales from operations (a) | (euro million) | 36,198 | 32,212 | 28,250 | |||||
Operating profit | (3,125 | ) | (2,967 | ) | 186 | ||||
Adjusted operating profit | 398 | (638 | ) | 310 | |||||
Adjusted net profit | 479 | (253 | ) | 190 | |||||
Capital expenditure | 213 | 229 | 172 | ||||||
Worldwide gas sales (b) | (bcm) | 95.32 | 93.17 | 89.17 | |||||
LNG sales (c) | 14.6 | 12.4 | 13.3 | ||||||
Customers in Italy | (million) | 7.45 | 8.00 | 7.93 | |||||
Electricity sales | (TWh) | 42.58 | 35.05 | 33.58 | |||||
Employees at year end | (number) | 4,836 | 4,616 | 4,228 | |||||
GHG emissions | (mmtonnes CO2 eq) | 12.77 | 11.22 | 10.08 | |||||
Customer satisfaction score (CSC) (d) | (%) | 89.7 | 92.9 | 93.4 | |||||
Water consumption/withdrawals per kWh eq produced | (cm/kWh eq) | 0.012 | 0.017 | 0.017 | |||||
(a) Before
elimination of intragroup sales. (b) Include volumes marketed by the Exploration & Production segment of 3.06 bcm (2.73 and 2.61 bcm in 2012 and 2013, respectively). (c) Refers to LNG sales of the Gas & Power segment (included in worldwide gas sales) and the Exploration & Production segment. (d) Data referred to the first half of 2014, as at the date of publication of this document Authority for Electricity Gas and Water (AEEGSI) hasnt published yet the data for the second part of the year. |
2014 |
Highlights |
|
Performance of the year è In 2014, employees and contractors injury frequency rates declined by 66%, in line with historical trends. è Greenhouse gas emissions decreased by 10.2% from 2013. è The water consumption rate of EniPowers plants decreased by 5.9% from 2013, while the same index per KWh produced was substantially stable. The decrease was due to lower use of sea water in cooling operations at Brindisi site and lower production of electricity at Livorno site, due to an unfavorable trading environment, with steam and freshwater consumption almost unchanged from 2013. è Eni gas sales (89.17 bcm) were down by 4.3% compared to 2013. Enis sales in the domestic market of 34.04 bcm |
decreased by 5.1% driven by
lower sales in all the business segments partially offset
by higher spot sales. Barely unchanged volumes marketed
in the main European markets (42.21 bcm; down by 1.1%). è Electricity sales of 33.58 TWh decreased by 1.47 TWh, or 4.2% compared to the previous year. è Capital expenditure of euro 172 million mainly concerned the flexibility and upgrading of combined cycle power stations (euro 98 million), as well as gas marketing initiatives (euro 66 million). è In 2014, adjusted net profit amounted to euro 190 million, up by euro 443 million from 2013. This reflected the benefits from the renegotiation of a substantial portion of the long-term gas supply |
portfolio, including larger
one-off effects related to the purchase costs of volumes
supplied in previous reporting periods. These positive
effects were partially offset by declining gas and power
prices against the backdrop of continuing weak demand and
competitive pressure. è In 2014, we achieved several renegotiations of our long-term gas supply contracts and we obtained a reduction in take-or-pay volumes. Approximately 70% of our long-term gas supply portfolio is now indexed to hub prices. Cash advances paid to suppliers due to the take-or-pay clause in those long-term supply contracts were reduced by euro 0.66 billion also leveraging on sales optimization. |
- 12 -
Gas & Power / Business review Eni in 2014
|
Strategies Eni's management expects a
weak outlook for natural gas sales and prices due to
structural headwinds in the industry as we forecast
demand stagnation, oversupplies and strong competition
across all of our main markets in Europe, including
Italy. Against this backdrop, European markets remains well supplied thanks to the fast development of liquid hubs where operators can trade spot gas. In 2013, approximately 62% of gas volumes supplied were traded at continental hubs. These trends will drive continuing competition and pricing pressure, which are expected to be exacerbated by the constraints of the long-term supply contracts |
with take-or-pay clauses
whereby wholesaler operators are forced to compete
aggressively on pricing in order to limit the financial
exposure dictated by the contracts. In Italy we expect that gas prices in the wholesale market will remain under pressure due to a number of negative factors including competitive pressure and the current level of minimum take volumes of Italian operators which are well above the absolute dimension of the Italian market. In the retail market, the regulated tariffs to residential and commercial users are currently indexed to spot prices of gas quoted at continental hubs. Based on the above outlined trends and industrial actions, management will try to retain profitable, cash-positive operations in the Companys gas marketing business over the plan period. To achieve this object we intend to put in place the
following strategic guidelines: |
Gas & Power value chain |
Enis Gas & Power segment engages in all phases of the natural gas value chain: supply, trading and marketing of natural gas and LNG. This segment also includes power generation and marketing of electricity. Enis leading position in the European gas market is ensured by a set of competitive advantages, including our multi-country approach, long-term gas availability, access to infrastructures, market knowledge and a strong customer base, in addition to long-term relations with producing countries. Furthermore, integration with our upstream operations provides valuables growth options whereby the Company targets to monetize its large gas reserves.
- 13 -
Refining & Marketing / Business review Eni in 2014
Key performance indicators | |||
2012 | 2013 | 2014 |
Injury frequency rate of total Eni workforce | (No. of accidents per million of worked hours) | 1.74 | 1.01 | 0.86 | |||||
Net sales from operations (a) | (euro million) | 62,531 | 57,238 | 56,153 | |||||
Operating profit | (1,264 | ) | (1,492 | ) | (2,229 | ) | |||
Adjusted operating profit | (289 | ) | (457 | ) | (208 | ) | |||
Adjusted net profit | (181 | ) | (232 | ) | (147 | ) | |||
Capital expenditure | 898 | 672 | 537 | ||||||
Refinery throughputs on own account | (mmtonnes) | 30.01 | 27.38 | 25.03 | |||||
Conversion index | (%) | 61 | 62 | 51 | |||||
Balanced capacity of refineries | (kbbl/d) | 767 | 787 | 617 | |||||
Retail sales of petroleum products in Europe | (mmtonnes) | 10.87 | 9.69 | 9.21 | |||||
Service stations in Europe at year end | (number) | 6,384 | 6,386 | 6,220 | |||||
Average throughput per service station in Europe | (kliters) | 2,064 | 1,828 | 1,725 | |||||
Retail efficiency index | (%) | 1.48 | 1.28 | 1.19 | |||||
Employees at year end | (number) | 8,608 | 8,438 | 6,774 | |||||
GHG emissions | (mmtonnes CO2 eq) | 6.06 | 5.20 | 5.34 | |||||
SOx (sulphur oxide) emissions | (ktonnes SO2 eq) | 16.99 | 10.80 | 6.09 | |||||
Water consumption rate (refineries)/refinery throughputs | (cm/tonnes) | 25.43 | 19.98 | 22.42 | |||||
Bio-fuels marketed | (mmtonnes) | 14.83 | 10.84 | 12.93 | |||||
Customer satisfaction index | (Likert scale) | 7.90 | 8.10 | 8.20 | |||||
(a) Before elimination of intragroup sales. |
2014 |
Highlights |
|
Performance of the year è In 2014, the injury frequency rate for employees and contractors was down 14.9% demonstrating our continuing commitment for a more secure workplace. è In 2014, the Refining & Marketing segment reduced the adjusted net loss to euro 147 million (euro 232 million in 2013) driven by improved margins and restructuring initiatives, including the start-up of the green refinery project in Venice, and cost efficiencies. è In 2014, refining throughputs were 25.03 mmtonnes, down by 8.6% from 2013. In Italy, processed volumes decreased by 11.7% mainly due to the unfavorable refinery scenario registered in the first part of the year and the shutdown of the Gela and Venice refineries. è In 2014, the production of bio-fuels amounted to 12.93 mmtonnes, up by |
19.3% compared to a year ago
following the start-up of the bio-refinery in Venice. è Retail sales in Italy amounted to 6.14 mmtonnes, down by 7.5% from 2013 due to strong competitive pressure. In 2014, Enis average retail market share was 25.5%, down by 2 percentage points from 2013. è Retail sales in the rest of Europe of 3.07 mmtonnes were substantially stable compared to 2013 (up by 0.7%). Higher volumes marketed in Germany and Austria were offset by lower sales of other subsidiaries. è Capital expenditure amounted to euro 537 million mainly related to the reconversion of the Venice refinery and improvement of flexibility and yields of the other plants, in particular at Sannazzaro refinery and the rebranding of the retail distribution network. |
è In 2014, expenditure in
R&D amounted to approximately euro 18 million. During
the year, 15 patent applications were filed. Portfolio
rationalization |
- 14 -
Development plan of the
Gela site è In November 2014, Eni defined with the Ministry for Economic Development, the Region of Sicily and interested stakeholders a plan to restore the profitability of the Gela refinery. The key point of the agreement is the reconversion of the Gela site to a bio-refinery. è The reconversion will follow the model adopted for the Venice green refinery, by leveraging on raw vegetable materials and use of the proprietary technologies. |
The agreement also defines terms for building a modern logistic hub and new initiatives in the upstream sector in Sicily, including offshore. Eni will also perform environmental remediation and clean-up activities and institute the Safety Competence Center (SCC), a center of excellence in the security field. The investment plan for such initiatives amounts to euro 2.2 billion, mainly relating to upstream projects in the Sicily region. | Start-up of Venice
bio-refinery è In June 2014, the start-up of the bio-refinery of Porto Marghera was achieved, with a green diesel capacity of 300 ktonnes/y. The green diesel is produced from refined vegetable oil utilizing the proprietary EcofiningTM technology. The production will fulfill half of the Enis annual requirement of green diesel, thus ensuring new perspectives for the industrial site of Venice and allowing economic and environmental benefits. |
|
Strategies For the next four years, the priority of Eni's Refining & Marketing segment is to return to profitability in the context of weak fundamentals of the European refining market, affected by weak demand, structural overcapacity and competitive pressure from streams of cheaper products from Asia, Russia and the United States. Against this scenario, the Company priority is to
recover the economic and financial sustainability in a
short timeframe, targeting to break even at both adjusted
operating profit and cash generation before investment in
2015, then to stabilize profitability and cash generation
in the long run. In order to achieve this goal, our
strategy in the Refining & Marketing sector will
leverage on reducing and rationalizing refining capacity
in order to limit the Companys exposure to volatile
refining margins, and on efficiency initiatives. We are
planning for a 50% capacity cut (2012 base) which, once
implemented, will bring our installed capacity in line
with our targeted exposure to the refining business
considering our view of industry trends and fundamentals. |
We believe that the
restructuring initiatives implemented so far have reduced
the refining break-even margin. Going forward, we plan to
divest our interests in certain refining assets abroad
and to downsize our less competitive Italian refineries.
We intend to make selective capital expenditures
expecting to invest approximately euro 1 billion to
improve efficiency and optimize existing plant, to
complete the bio-refinery at the Venice site and to
implement the Gela project. We have defined other
initiatives designed to provide for: In Marketing activities, where we expect continuing competitive pressure due to weak demand trends and oversupplies in our core domestic market, we are planning to achieve a gradual improvement in results of operations mainly by focusing on margin preservation and cost efficiencies. We will try to do this by means of effective marketing initiatives to retain customers, product and service innovation and a continuing focus on the quality of service, as well as the expansion of non-oil activities. Management plans to improve the efficiency of the Italian retail network by closing low-throughput outlets and other rationalizations. Retail operations abroad will be focused on those areas and markets where we expect attractive profitability due to an improving scenario for consumption, while we plan to divest our presence in marginal areas, mainly in Eastern Europe. |
- 15 -
Versalis / Business review Eni in 2014
Key performance indicators | |||
2012 | 2013 | 2014 |
Injury frequency rate of total Eni workforce | (No. of accidents per million of worked hours) | 1.09 | 0.57 | 0.28 | |||||
Net sales from operations (a) | (euro million) | 6,418 | 5,859 | 5,284 | |||||
Intermediates | 3,050 | 2,709 | 2,310 | ||||||
Polymers | 3,188 | 2,933 | 2,800 | ||||||
Other sales | 180 | 217 | 174 | ||||||
Operating profit | (681 | ) | (725 | ) | (704 | ) | |||
Adjusted operating profit | (483 | ) | (386 | ) | (346 | ) | |||
Adjusted net profit | (395 | ) | (338 | ) | (277 | ) | |||
Capital expenditure | 172 | 314 | 282 | ||||||
Production | (mmtonnes) | 6,090 | 5,817 | 5,283 | |||||
Sales of petrochemical products | 3,953 | 3,785 | 3,463 | ||||||
Average plant utilization rate | (%) | 66.7 | 65.3 | 71.3 | |||||
Employees at year end | (number) | 5,668 | 5,708 | 5,443 | |||||
GHG emissions | (mmtonnes CO2 eq) | 3.72 | 3.69 | 3.09 | |||||
NMVOC (Non-Methane Volatile Organic Compound) emissions | (ktonnes) | 4.40 | 3.93 | 3.51 | |||||
NOx (nitrogen oxide) emissions | (ktonnes NO2 eq) | 3.43 | 3.29 | 2.45 | |||||
Recycled/reused water | (%) | 81.6 | 86.2 | 87.7 | |||||
(a) Before elimination of intragroup sales. |
2014 |
Highlights |
|
Performance of the year è In 2014, the injury frequency rate (employees and contractors) was more than halved (down by 50.9%) compared to 2013, in continuation of historical positive trend. è In 2014, greenhouse gas emissions and other emissions in the atmosphere were lower than in 2013 (down by 16.3%), following the restructuring of the production assets. Recycled/reused water rate improved, up to 87.7%. è In 2014, adjusted net loss was euro 277 million, euro 61 million lower than in 2013, benefiting from improved margins of intermediates and polyethylene. Results reflected efficiency initiatives and restructuring programs, mainly relating to the start-up of the Porto Torres Green Chemical project and the shutdown of certain unprofitable production units. è Sales of petrochemical products amounted to 3,463 ktonnes, down by 322 ktonnes, or 8.5% from 2013, driven by weak commodity |
demand and strong
competition. è In 2014, expenditure in R&D amounted to approximately euro 40 million, 14 patent applications were filed. Restructuring
of petrochemical activities in Sardinia |
è At the end of December 2014,
Versalis signed an agreement to divest the Sarroch plant
to the refining company Saras, which owns a refinery
close to Enis petrochemical site. The agreement
includes the disposal of the Versalis plants connected
with the production cycle of the refinery, in particular
the reforming unit, the propylene splitter unit and other
related services, including the logistics system. The
Green Chemical project of Porto Marghera |
- 16 -
new technology for the
production of bio-chemical intermediates from vegetable
oils destined for high added-value industrial
applications such as detergents, bio-lubricants and
chemicals for the oil industry. Development and
sustainability initiatives |
US-based renewable oil and
bio-products company, aimed to expand market access and
commercial use of Encapso™ the worlds
first commercially available, biodegradable
encapsulated lubricants for drilling fluids. Encapso will
also be used in oil and gas fields operated by Eni. è Following the strategic partnership signed in 2013 with Yulex, an US- |
based leader in bio-materials, to produce guayule-based bio-rubber by using non-food feedstock, is under development the agronomic protocol and the innovative technology engineering, through the development of the entire supply chain, from the cultivation to the extraction of natural rubber, until the construction of a bio-mass power station. |
|
Strategies Versalis operations are exposed to volatile costs of oil-based feedstock and the cyclicality of demand due to the commoditized nature of product portfolio and underlying weaknesses in the industry. Our commodity chemical businesses have been unprofitable in recent years and we expect only limited improvements in the scenario in the foreseeable future due to structural cost disadvantages with respect to Asian and Middle East players and also US players, as well as a weak macroeconomic outlook which will hamper a sustainable recovery in demand. We believe that the current improvement in the cost of oil-based feedstock will provide only limited upside to the weak underlying fundamentals of the petrochemical sector in Europe. Against this backdrop, our priority is the economic and financial sustainability in the medium and long term. The breakeven at |
adjusted operating profit
and operating cash flow is expected to be achieved from
2016. This target will be driven by implementing the
following strategic guidelines: |
- 17 -
Engineering & Construction / Business review Eni in 2014
Key performance indicators | |||
2012 | 2013 | 2014 |
Injury frequency rate of total Eni workforce | (No. of accidents per million of worked hours) | 0.32 | 0.26 | 0.28 | |||||
Net sales from operations (a) | (euro million) | 12,799 | 11,598 | 12,873 | |||||
Operating profit | 1,453 | (98 | ) | 18 | |||||
Adjusted operating profit | 1,485 | (99 | ) | 479 | |||||
Adjusted net profit | 1,111 | (253 | ) | 309 | |||||
Capital expenditure | 1,011 | 902 | 694 | ||||||
Orders acquired | (euro million) | 13,391 | 10,062 | 17,971 | |||||
Order backlog | 19,739 | 17,065 | 22,147 | ||||||
Employees at year end | (number) | 43,387 | 47,209 | 49,559 | |||||
Employees outside Italy rate | (%) | 88.1 | 89.1 | 89.9 | |||||
Local managers rate | 41.3 | 41.3 | 42.0 | ||||||
Local procurement rate | 57.4 | 54.3 | 55.6 | ||||||
GHG emissions | (mmtonnes CO2 eq) | 1.54 | 1.54 | 1.42 | |||||
Water withdrawals | (million of cubic meters) | 8.25 | 8.74 | 6.32 | |||||
(a) Before elimination of intragroup sales. |
2014 |
Highlights |
|
Performance of the year è In 2014, the injury frequency rate registered a 7.7% increase due to a poor performance for contractors (up by 12.7%), partially offset by a lower injury frequency rate for employees (down by 4.9%). è In 2014, adjusted net profit of the Engineering & Construction segment amounted to euro 309 million, up by euro 562 |
million from the adjusted
net loss of euro 253 million reported in 2013, which was
driven by extraordinary contract losses. è Orders acquired amounted to euro 17,971 million (euro 10,062 million in 2013), 97% of which relating to the works outside Italy, while orders from Eni companies amounted to 8% of the total. è Order backlog amounted to euro 22,147 |
million at December 31, 2014
(euro 17,065 million at December 31, 2013), of which euro
9,035 million to be executed in 2015. è Expenditure in R&D amounted to euro 12 million. 20 patent applications were filed. è Capital expenditure amounted to euro 694 million (euro 902 million in 2013) which mainly regarded the upgrading of the drilling and construction fleet. |
| Strategies We expect a challenging trading environment in the oilfield services sector due to lower crude oil prices. In spite of this, we forecast that the execution of recently-acquired projects will support operating results. Over the four-year plan, the Engineering & Construction segment intends to improve profitability by growing in those |
market segments where it owns competitive advantages, like ultra-deep projects, pipeline laying, onshore projects in harsh environments and with other complexities. The Engineering & Construction segment will leverage on the enhancement of the EPC(I)-oriented business model, its world-class technology, engineering and delivering skills, its strong local presence and established relationships with other major oil companies and national oil companies. The profitability and cash generation over the plan period will be sustained by selective capital expenditure, efficiency actions and working capital optimization. |
- 18 -
- 19 -
Group results for the year / Financial review Eni in 2014
Group results for the year
In 2014, the Group faced
strong headwinds in any of its reference markets.
Oil&gas realizations in dollar terms declined due to
lower a Brent price, down by 9% from 2013, and lower gas
benchmarks. Enis refining margins (Standard Eni
Refining Margin-SERM) that gauge the profitability of
Enis refineries were up by 32.1% from the
particularly depressed level of 2013, due to a fall in
the cost of crude oil feedstock. However, the European
refining business continued to be affected by structural
headwinds from lower demand, overcapacity and increasing
competitive pressure from streams of cheaper refined
products imported from Russia, Asia and the United
States. The European gas market was adversely affected by
weak demand, competitive pressures and oversupply. Price
competition was tough taking into account minimum
off-take obligations provided by gas purchase take-or-pay
contracts and reduced sales opportunities. Spot prices in
Europe reported a decrease of 22.7% from 2013.
Electricity sales reported negative margins due to
oversupply and increasing competition from more
competitive sources (photovoltaic and coal-fired plants). | 2014 results In 2014, net profit attributable to Enis
shareholders was euro 1,291 million, a decline of
euro 3,869 million from 2013, or 75%; operating profit of
euro 7,917 million was down by 10.9%. |
affected by a euro 221
million loss on the fair-valued interests in Galp and
Snam which underlay two convertible bonds. In addition to these business trends, 2014 net profit was impacted by net charges of euro 2,416 million due to the alignment of crude oil and product inventories to current market prices, asset impairments driven by a lower price environment in the near to medium term impacting the recoverable amounts of oil&gas properties and of rigs and construction vessels in Saipem, as well as the write-off of deferred tax assets of Italian subsidiaries (euro 976 million) due to the projections of lower future taxable profit (euro 500 million) and the write-off for euro 476 million of deferred tax assets accrued in connection with an Italian windfall tax of 6.5 percentage points which adds to the Italian statutory tax rate of 27.5%. This windfall tax, the so-called Robin Tax, was ruled to be illegitimate by an Italian Court on February 11, 2015. It was the first time that a sentence stated the illegitimacy of a tax rule prospectively, denying any reimbursement right. As a result of the abrogation, deferred tax assets of Italian subsidiaries were recalculated with the lower statutory tax rate of 27.5% instead of 33%, with the difference being written off. These effects were partly offset by the recognition of a tax gain of euro 824 million due to the settlement of a tax dispute with the Italian fiscal Authorities regarding how to determine a tax surcharge of 4% due by the parent company Eni SpA (the so-called Libyan tax) since 2009. In 2013, significant disposal gains were recognized due to the divestment of a 20% stake in the Mozambique discovery (euro 2,994 million) and the fair-value evaluation of Enis interest in Artic Russia (euro 1,682 million), partly offset by extraordinary charges and inventory holding losses for euro 4 billion (post-tax). These transactions affected the year-on-year comparison of reported net profit. In 2014, adjusted net profit attributable to Enis shareholders of euro 3,707 million decreased by 16.3% and excludes an inventory holding loss of euro 1,008 million and special charges of euro 1,408 million, net of tax, with a positive adjustment of euro 2,416 million. |
- 20 -
Group results for the year / Financial review Eni in 2014
Adjusted net profit | |||||
2012 | (euro million) | 2013 | 2014 | Change | % Ch. |
4,200 | Net profit attributable to Eni's shareholders - continuing operations | 5,160 | 1,291 | (3,869 | ) | (75.0 | ) | ||||||
(23 | ) | Exclusion of inventory holding (gains) losses | 438 | 1,008 | |||||||||
2,953 | Exclusion of special items | (1,168 | ) | 1,408 | |||||||||
7,130 | Adjusted net profit attributable to Enis shareholders - continuing operations (a) | 4,430 | 3,707 | (723 | ) | (16.3 | ) | ||||||
(a) For a detailed explanation of adjusted operating profit and net profit see paragraph "Reconciliation of reported operating and net profit to results on an adjusted basis". |
The breakdown of adjusted net profit by segment is shown in the table below:
Adjusted net profit by segment | |||||
2012 | (euro million) | 2013 | 2014 | Change | % Ch. |
7,426 | Exploration & Production | 5,950 | 4,423 | (1,527 | ) | (25.7 | ) | ||||||
479 | Gas & Power | (253 | ) | 190 | ) | 443 | .. | ||||||
(181 | ) | Refining & Marketing | (232 | ) | (147 | ) | 85 | 36.6 | |||||
(395 | ) | Versalis | (338 | ) | (277 | ) | 61 | 18.0 | |||||
1,111 | Engineering & Construction | (253 | ) | 309 | 562 | .. | |||||||
(247 | ) | Other activities | (205 | ) | (200 | ) | 5 | 2.4 | |||||
(977 | ) | Corporate and financial companies | (484 | ) | (651 | ) | (167 | ) | (34.5 | ) | |||
661 | Impact of unrealized intragroup profit elimination (a) | 39 | 152 | 113 | |||||||||
7,877 | Adjusted net profit - continuing operations | 4,224 | 3,799 | (425 | ) | (10.1 | ) | ||||||
of which attributable to: | |||||||||||||
747 | - non-controlling interest | (206 | ) | 92 | 298 | .. | |||||||
7,130 | - Eni's shareholders | 4,430 | 3,707 | (723 | ) | (16.3 | ) | ||||||
(a) This item concerned mainly intragroup sales of commodities, services and capital goods recorded in the assets of the purchasing business segment at the reporting date. |
Results by business segment
Exploration
& Production The Exploration & Production segment reported a 21.1% decrease in adjusted operating profit to euro 11,551 million. This result reflected reduced oil and gas realizations in dollar terms (down by 8.9% on average) higher depreciation charges taken in connection with the start-up of new fields mainly in the second half of 2013, achieving full ramp-up in the course of 2014. Adjusted net profit of euro 4,423 million decreased by 25.7% due to a reduced operating performance. The adjusted tax rate increased by approximately 2 percentage points in the year due to a larger share of taxable profit reported in countries with higher taxations. Gas & Power |
Refining
& Marketing The Refining & Marketing segment reported half-sized operating losses at euro 208 million compared to 2013, in spite of continuing industry headwinds on the back of weak demand and overcapacity. The improvement was driven by improved refining margins compared with the particularly depressed scenario of 2013 following a fall in oil prices, and restructuring initiatives, including the start of the green refinery project in Venice, and cost efficiencies, particularly with respect to energy and overhead costs. Marketing results were sustained by a decline of oil prices despite weak demand and rising competitive pressure. The adjusted net loss for the full year was euro 147 million, down by euro 85 million from the previous reporting period. Versalis Engineering &
Construction |
- 21 -
Group results for the year / Financial review Eni in 2014
Capital expenditure
2012 | (euro million) | 2013 | 2014 | Change | % Ch. |
10,307 | Exploration & Production | 10,475 | 10,524 | 49 | 0.5 | ||||||||
43 | - acquisition of proved and unproved properties | 109 | |||||||||||
1,850 | - exploration | 1,669 | 1,398 | ||||||||||
8,304 | - development | 8,580 | 9,021 | ||||||||||
110 | - other expenditure | 117 | 105 | ||||||||||
213 | Gas & Power | 229 | 172 | (57 | ) | (24.9 | ) | ||||||
200 | - marketing | 206 | 164 | ||||||||||
13 | - international transport | 23 | 8 | ||||||||||
898 | Refining & Marketing | 672 | 537 | (135 | ) | (20.1 | ) | ||||||
675 | - refining, supply and logistics | 497 | 362 | ||||||||||
223 | - marketing | 175 | 175 | ||||||||||
172 | Versalis | 314 | 282 | (32 | ) | (10.2 | ) | ||||||
1,011 | Engineering & Construction | 902 | 694 | (208 | ) | (23.1 | ) | ||||||
14 | Other activities | 21 | 30 | 9 | 42.9 | ||||||||
152 | Corporate and financial companies | 190 | 83 | (107 | ) | (56.3 | ) | ||||||
38 | Impact of unrealized intragroup profit elimination | (3 | ) | (82 | ) | (79 | ) | ||||||
12,805 | Capital expenditure - continuing operations | 12,800 | 12,240 | (560 | ) | (4.4 | ) | ||||||
756 | Capital expenditure - discontinued operations | ||||||||||||
13,561 | Capital expenditure | 12,800 | 12,240 | (560 | ) | (4.4 | ) | ||||||
In 2014, capital expenditure
amounted to euro 12,240 million (euro 12,800 million in
2013) relating mainly to: - development activities deployed mainly in Norway, Angola, Congo, the United States, Italy, Nigeria, Egypt, Kazakhstan, Indonesia and exploratory activities of which 98% was spent outside Italy, primarily in Libya, Mozambique, the United States, Angola, Nigeria, Indonesia, Cyprus, Norway and Gabon; - upgrading of the fleet used in the Engineering & Construction segment (euro 694 million); - refining, supply and logistics in Italy and outside Italy (euro 362 million) with projects designed to improve the conversion rate and flexibility of refineries, as well as the upgrade and rebranding of the refined product retail network in Italy and in the rest of Europe (euro 175 million); and - initiatives to improve flexibility of the combined cycle power plants (euro 98 million). Sources
and uses of cash |
operations, borrowings and
divestments. In 2014, net cash provided by operating activities amounted to euro 15,110 million, as it was supported by a reduction of working capital in E&P, G&P mainly due to a reduction in cash advances related to the take-or-pay clause in gas long-term supply contracts, as well as in Saipem. Proceeds from disposals were euro 3,684 million and mainly related to the divestment of Enis share in Artic Russia (euro 2,160 million), an 8% interest in Galp Energia (euro 824 million), Enis interest in the EnBW joint venture in Germany, as well as the divestment of Enis stake in the South Stream project. These cash inflows funded cash outlays relating to capital expenditure totaling euro 12,240 million and dividend payments, share repurchases and other changes amounting to euro 4,434 million (including euro 2,020 million related to the 2014 interim dividend paid to Enis shareholders and euro 380 million of share repurchases), reducing the Groups net debt from December 31, 2013 by euro 1,278 million. Net cash provided by operating activities was negatively affected by lower receivables due beyond the end of the reporting period, being transferred to financing institutions compared to the amount transferred at the end of the previous reporting period (down by euro 961 million from December 31, 2013). |
- 22 -
Group results for the year / Financial review Eni in 2014
| Profit and loss account
2012 | (euro million) | 2013 | 2014 | Change | % Ch. |
127,109 | Net sales from operations | 114,697 | 109,847 | (4,850 | ) | (4.2 | ) | ||||||
1,548 | Other income and revenues | 1,387 | 1,101 | (286 | ) | (20.6 | ) | ||||||
(99,674 | ) | Operating expenses | (95,304 | ) | (91,677 | ) | 3,627 | 3.8 | |||||
(158 | ) | Other operating income (expense) | (71 | ) | 145 | 216 | .. | ||||||
(13,617 | ) | Depreciation, depletion, amortization and impairments | (11,821 | ) | (11,499 | ) | 322 | 2.7 | |||||
15,208 | Operating profit | 8,888 | 7,917 | (971 | ) | (10.9 | ) | ||||||
(1,371 | ) | Finance income (expense) | (1,009 | ) | (1,065 | ) | (56 | ) | (5.6 | ) | |||
2,789 | Net income from investments | 6,085 | 490 | (5,595 | ) | (91.9 | ) | ||||||
16,626 | Profit before income taxes | 13,964 | 7,342 | (6,622 | ) | (47.4 | ) | ||||||
(11,679 | ) | Income taxes | (9,005 | ) | (6,492 | ) | 2,513 | 27.9 | |||||
70.2 | Tax rate (%) | 64.5 | 88.4 | 23.9 | |||||||||
4,947 | Net profit - continuing operations | 4,959 | 850 | (4,109 | ) | (82.9 | ) | ||||||
3,732 | Net profit - discontinued operations | ||||||||||||
8,679 | Net profit | 4,959 | 850 | (4,109 | ) | (82.9 | ) | ||||||
Attributable to: | |||||||||||||
7,790 | Eni's shareholders: | 5,160 | 1,291 | (3,869 | ) | (75.0 | ) | ||||||
4,200 | - continuing operations | 5,160 | 1,291 | (3,869 | ) | (75.0 | ) | ||||||
3,590 | - discontinued operations | ||||||||||||
889 | Non-controlling interest: | (201 | ) | (441 | ) | (240 | ) | .. | |||||
747 | - continuing operations | (201 | ) | (441 | ) | (240 | ) | .. | |||||
142 | - discontinued operations | ||||||||||||
Non-GAAP
measures
Reconciliation of
reported operating profit and reported
net profit to results on an adjusted basis
Management evaluates Group
and business performance on the basis of adjusted
operating profit and adjusted net profit, which are
arrived at by excluding inventory holding gains or
losses, special items and, in determining the business
segments adjusted results, finance charges on
finance debt and interest income. The adjusted operating
profit of each business segment reports gains and losses
on derivative financial instruments entered into to
manage exposure to movements in foreign currency exchange
rates which impact industrial margins and translation of
commercial payables and receivables. Accordingly also
currency translation effects recorded through profit and
loss are reported within business segments adjusted
operating profit. The taxation effect of the items excluded from adjusted operating or net profit is determined based on the specific rate of taxes applicable to each of them. The Italian statutory tax rate is applied to finance charges and income. Adjusted operating profit and adjusted net profit are non-GAAP financial measures under either IFRS, or US GAAP. Management includes them in order to facilitate a comparison of base business performance across periods, and to allow financial analysts to evaluate Enis trading performance on the basis of their forecasting models. The following is a description of items that are excluded from the calculation of adjusted results. Inventory holding gain or loss is the difference between the cost of sales of the volumes sold in the period based on the cost of supplies of the same period and the cost of sales of the volumes |
sold calculated using the
weighted average cost method of inventory accounting. Special
items include certain significant income or charges
pertaining to either: (i) infrequent or unusual events
and transactions, being identified as non-recurring items
under such circumstances; (ii) certain events or
transactions which are not considered to be
representative of the ordinary course of business, as in
the case of environmental provisions, restructuring
charges, asset impairments or write ups and gains or
losses on divestments even though they occurred in past
periods or are likely to occur in future ones; or (iii)
exchange rate differences and derivatives relating to
industrial activities and commercial payables and
receivables, particularly exchange rate derivatives to
manage commodity pricing formulas which are quoted in a
currency other than the functional currency. Those items
are reclassified in operating profit with a corresponding
adjustment to net finance charges, notwithstanding the
handling of foreign currency exchange risks is made
centrally by netting off naturally-occurring opposite
positions and then dealing with any residual risk
exposure in the exchange rate market. |
- 23 -
Group results for the year / Financial review Eni in 2014
derivatives relating to
commercial exposures, lacking the criteria to be designed
as hedges, including the ineffective portion of cash flow
hedges and certain derivative financial instruments
embedded in the pricing formula of long-term gas supply
agreements of the Exploration & Production segment. Finance charges or income related to net borrowings excluded from the adjusted net profit of business segments are comprised of interest charges on finance debt and interest income earned on cash and cash equivalents not related to operations. Therefore, the adjusted net profit of business segments includes finance charges or income deriving from |
certain segment-operated
assets, i.e., interest income on certain receivable
financing and securities related to operations and
finance charge pertaining to the accretion of certain
provisions recorded on a discounted basis (as in the case
of the asset retirement obligations in the Exploration
& Production segment). Finance charges or interest
income and related taxation effects excluded from the
adjusted net profit of the business segments are
allocated on the aggregate Corporate and financial
companies. For a reconciliation of adjusted operating profit, adjusted net profit to reported operating profit and reported net profit see tables below. |
2014 (euro million) |
Exploration
& Production |
Gas & Power |
Refining &
Marketing |
Versalis |
Engineering
& Construction |
Corporate and
financial companies |
Other activities |
Impact of
unrealized intragroup profit elimination |
GROUP |
Operating profit | 10,766 | 186 | (2,229 | ) | (704 | ) | 18 | (246 | ) | (272 | ) | 398 | 7,917 | ||||||||||||||
Exclusion of inventory holding (gains) losses | (119 | ) | 1,576 | 170 | (167 | ) | 1,460 | ||||||||||||||||||||
Exclusion of special items: | |||||||||||||||||||||||||||
- asset impairments | 692 | 25 | 284 | 96 | 420 | 14 | 1,531 | ||||||||||||||||||||
- gains on disposal of assets | (76 | ) | (2 | ) | 45 | 2 | 3 | (28 | ) | ||||||||||||||||||
- risk provisions | (5 | ) | (42 | ) | 25 | 5 | 7 | (10 | ) | ||||||||||||||||||
- environmental charges | 111 | 27 | 41 | 179 | |||||||||||||||||||||||
- provision for redundancy incentives | 24 | 11 | (6 | ) | 5 | (22 | ) | (3 | ) | 9 | |||||||||||||||||
- commodity derivatives | (28 | ) | (43 | ) | 42 | 4 | 9 | (16 | ) | ||||||||||||||||||
- exchange rate differences and derivatives | 6 | 228 | (9 | ) | 4 | 229 | |||||||||||||||||||||
- other | 172 | 64 | 25 | 12 | (2 | ) | 32 | 303 | |||||||||||||||||||
Special items of operating profit | 785 | 243 | 445 | 188 | 461 | (19 | ) | 94 | 2,197 | ||||||||||||||||||
Adjusted operating profit | 11,551 | 310 | (208 | ) | (346 | ) | 479 | (265 | ) | (178 | ) | 231 | 11,574 | ||||||||||||||
Net finance (expense) income (a) | (287 | ) | 7 | (9 | ) | (3 | ) | (6 | ) | (542 | ) | (22 | ) | (862 | ) | ||||||||||||
Net income from investments (a) | 323 | 49 | 67 | (3 | ) | 21 | (156 | ) | 301 | ||||||||||||||||||
Income taxes (a) | (7,164 | ) | (176 | ) | 3 | 75 | (185 | ) | 312 | (79 | ) | (7,214 | ) | ||||||||||||||
Tax rate (%) | 61.8 | 48.1 | .. | 37.4 | 65.5 | ||||||||||||||||||||||
Adjusted net profit | 4,423 | 190 | (147 | ) | (277 | ) | 309 | (651 | ) | (200 | ) | 152 | 3,799 | ||||||||||||||
of which attributable to: | |||||||||||||||||||||||||||
- non-controlling interest | 92 | ||||||||||||||||||||||||||
- Enis shareholders | 3,707 | ||||||||||||||||||||||||||
Net profit attributable to Enis shareholders | 1,291 | ||||||||||||||||||||||||||
Exclusion of inventory holding (gains) losses | 1,008 | ||||||||||||||||||||||||||
Exclusion of special items | 1,408 | ||||||||||||||||||||||||||
Adjusted net profit attributable to Enis shareholders | 3,707 |
(a) Excluding special items. |
- 24 -
Group results for the year / Financial review Eni in 2014
2013 (euro million) |
Exploration
& Production |
Gas & Power |
Refining &
Marketing |
Versalis |
Engineering
& Construction |
Corporate and
financial companies |
Other activities |
Impact of
unrealized intragroup profit elimination |
GROUP |
Operating profit | 14,868 | (2,967 | ) | (1,492 | ) | (725 | ) | (98 | ) | (399 | ) | (337 | ) | 38 | 8,888 | ||||||||||||
Exclusion of inventory holding (gains) losses | 191 | 221 | 213 | 91 | 716 | ||||||||||||||||||||||
Exclusion of special items: | |||||||||||||||||||||||||||
- asset impairments | 19 | 1,685 | 633 | 44 | 19 | 2,400 | |||||||||||||||||||||
- gains on disposal of assets | (283 | ) | 1 | (9 | ) | 107 | (3 | ) | (187 | ) | |||||||||||||||||
- risk provisions | 7 | 292 | 4 | 31 | 334 | ||||||||||||||||||||||
- environmental charges | (1 | ) | 93 | 61 | 52 | 205 | |||||||||||||||||||||
- provision for redundancy incentives | 52 | 10 | 91 | 23 | 2 | 72 | 20 | 270 | |||||||||||||||||||
- commodity derivatives | (2 | ) | 314 | 5 | (1 | ) | (1 | ) | 315 | ||||||||||||||||||
- exchange rate differences and derivatives | (2 | ) | (186 | ) | (2 | ) | (5 | ) | (195 | ) | |||||||||||||||||
- other | (16 | ) | 23 | 3 | (109 | ) | (5 | ) | 8 | (96 | ) | ||||||||||||||||
Special items of operating profit | (225 | ) | 2,138 | 814 | 126 | (1 | ) | 67 | 127 | 3,046 | |||||||||||||||||
Adjusted operating profit | 14,643 | (638 | ) | (457 | ) | (386 | ) | (99 | ) | (332 | ) | (210 | ) | 129 | 12,650 | ||||||||||||
Net finance (expense) income (a) | (264 | ) | 14 | (6 | ) | (2 | ) | (5 | ) | (571 | ) | 4 | (830 | ) | |||||||||||||
Net income from investments (a) | 367 | 70 | 56 | 2 | 290 | 1 | 786 | ||||||||||||||||||||
Income taxes (a) | (8,796 | ) | 301 | 175 | 50 | (151 | ) | 129 | (90 | ) | (8,382 | ) | |||||||||||||||
Tax rate (%) | 59.7 | .. | .. | .. | 41.5 | 66.5 | |||||||||||||||||||||
Adjusted net profit | 5,950 | (253 | ) | (232 | ) | (338 | ) | (253 | ) | (484 | ) | (205 | ) | 39 | 4,224 | ||||||||||||
of which attributable to: | |||||||||||||||||||||||||||
- non-controlling interest | (206 | ) | |||||||||||||||||||||||||
- Enis shareholders | 4,430 | ||||||||||||||||||||||||||
Net profit attributable to Enis shareholders | 5,160 | ||||||||||||||||||||||||||
Exclusion of inventory holding (gains) losses | 438 | ||||||||||||||||||||||||||
Exclusion of special items | (1,168 | ) | |||||||||||||||||||||||||
Adjusted net profit attributable to Enis shareholders | 4,430 |
(a) Excluding special items. |
- 25 -
Group results for the year / Financial review Eni in 2014
2012 (euro million) |
Exploration
& Production |
Gas & Power |
Refining &
Marketing |
Versalis |
Engineering
& Construction |
Corporate and
financial companies |
OTHER
ACTIVITIES |
Impact of
unrealized intragroup profit elimination |
GROUP |
DISCONTINUED
OPERATIONS |
CONTINUING
OPERATIONS |
|||
Snam |
Other activities |
Snam |
Consolidation
adjustments |
Total |
Operating profit | 18,470 | (3,125 | ) | (1,264 | ) | (681 | ) | 1,453 | (341 | ) | 1,679 | (300 | ) | 208 | 16,099 | (1,679 | ) | 788 | (891 | ) | 15,208 | |||||||||||||||||||||
Exclusion of inventory holding (gains) losses | 163 | (29 | ) | 63 | (214 | ) | (17 | ) | (17 | ) | ||||||||||||||||||||||||||||||||
Exclusion of special items: | ||||||||||||||||||||||||||||||||||||||||||
- asset impairments | 550 | 2,443 | 846 | 112 | 25 | 2 | 3,978 | 3,978 | ||||||||||||||||||||||||||||||||||
- gains on disposal of assets | (542 | ) | (3 | ) | 5 | 1 | 3 | (22 | ) | (12 | ) | (570 | ) | 22 | 22 | (548 | ) | |||||||||||||||||||||||||
- risk provisions | 7 | 831 | 49 | 18 | 5 | 35 | 945 | 945 | ||||||||||||||||||||||||||||||||||
- environmental charges | (2 | ) | 40 | 71 | 25 | 134 | (71 | ) | (71 | ) | 63 | |||||||||||||||||||||||||||||||
- provision for redundancy incentives | 6 | 5 | 19 | 14 | 7 | 11 | 2 | 2 | 66 | (2 | ) | (2 | ) | 64 | ||||||||||||||||||||||||||||
- commodity derivatives | 1 | 1 | (3 | ) | (1 | ) | (1 | ) | ||||||||||||||||||||||||||||||||||
- exchange rate differences and derivatives | (9 | ) | (52 | ) | (8 | ) | (11 | ) | (80 | ) | (80 | ) | ||||||||||||||||||||||||||||||
- other | 54 | 138 | 53 | 26 | 271 | 271 | ||||||||||||||||||||||||||||||||||||
Special items of operating profit | 67 | 3,360 | 1,004 | 135 | 32 | 16 | 51 | 78 | 4,743 | (51 | ) | (51 | ) | 4,692 | ||||||||||||||||||||||||||||
Adjusted operating profit | 18,537 | 398 | (289 | ) | (483 | ) | 1,485 | (325 | ) | 1,730 | (222 | ) | (6 | ) | 20,825 | (1,730 | ) | 788 | (942 | ) | 19,883 | |||||||||||||||||||||
Net finance (expense) income (a) | (264 | ) | 11 | (14 | ) | (3 | ) | (7 | ) | (867 | ) | (54 | ) | (24 | ) | (1,222 | ) | 54 | 54 | (1,168 | ) | |||||||||||||||||||||
Net income from investments (a) | 436 | 233 | 43 | 2 | 46 | 99 | 38 | (1 | ) | 896 | (38 | ) | (38 | ) | 858 | |||||||||||||||||||||||||||
Income taxes (a) | (11,283 | ) | (163 | ) | 79 | 89 | (413 | ) | 116 | (712 | ) | 2 | (12,285 | ) | 712 | (123 | ) | 589 | (11,696 | ) | ||||||||||||||||||||||
Tax rate (%) | 60.3 | 25.4 | .. | 27.1 | 41.5 | 59.9 | 59.8 | |||||||||||||||||||||||||||||||||||
Adjusted net profit | 7,426 | 479 | (181 | ) | (395 | ) | 1,111 | (977 | ) | 1,002 | (247 | ) | (4 | ) | 8,214 | (1,002 | ) | 665 | (337 | ) | 7,877 | |||||||||||||||||||||
of which attributable to: | ||||||||||||||||||||||||||||||||||||||||||
- non-controlling interest | 889 | (142 | ) | 747 | ||||||||||||||||||||||||||||||||||||||
- Enis shareholders | 7,325 | (195 | ) | 7,130 | ||||||||||||||||||||||||||||||||||||||
Net profit attributable to Enis shareholders | 7,790 | (3,590 | ) | 4,200 | ||||||||||||||||||||||||||||||||||||||
Exclusion of inventory holding (gains) losses | (23 | ) | (23 | ) | ||||||||||||||||||||||||||||||||||||||
Exclusion of special items | (442 | ) | 3,395 | 2,953 | ||||||||||||||||||||||||||||||||||||||
Adjusted net profit attributable to Enis shareholders | 7,325 | (195 | ) | 7,130 |
(a) Excluding special items. |
- 26 -
Group results for the year / Financial review Eni in 2014
Breakdown of special items
2012 | (euro million) | 2013 | 2014 |
4,743 | Special items of operating profit | 3,046 | 2,197 | ||||||
3,978 | - asset impairment | 2,400 | 1,531 | ||||||
(570 | ) | - gains on disposal of assets | (187 | ) | (28 | ) | |||
945 | - risk provisions | 334 | (10 | ) | |||||
134 | - environmental charges | 205 | 179 | ||||||
66 | - provision for redundancy incentives | 270 | 9 | ||||||
(1 | ) | - commodity derivatives | 315 | (16 | ) | ||||
(80 | ) | - exchange rate differences and derivatives | (195 | ) | 229 | ||||
271 | - other | (96 | ) | 303 | |||||
203 | Net finance (income) expense | 179 | 203 | ||||||
of which: | |||||||||
80 | - exchange rate differences and derivatives | 195 | (229 | ) | |||||
(5,373 | ) | Net income from investments | (5,299 | ) | (189 | ) | |||
of which: | |||||||||
(2,354 | ) | gains on disposal of assets | (3,599 | ) | (159 | ) | |||
of which: | |||||||||
divestment of the 28.57% of Enis interest in Eni East Africa | (3,359 | ) | |||||||
(311 | ) | Galp | (98 | ) | (96 | ) | |||
(2,019 | ) | Snam | (75 | ) | |||||
South Stream | (54 | ) | |||||||
(3,151 | ) | gains on investment revaluation | (1,682 | ) | |||||
of which: | |||||||||
(1,700 | ) | Galp | |||||||
(1,451 | ) | Snam | |||||||
Artic Russia | (1,682 | ) | |||||||
191 | impairments of equity investments | 11 | (38 | ) | |||||
(15 | ) | Income taxes | 901 | (270 | ) | ||||
of which: | |||||||||
803 | - impairment of deferred tax assets of Italian subsidiaries | 954 | 976 | ||||||
- other tax profit | (824 | ) | |||||||
- deferred tax adjustment on PSAs | 490 | 69 | |||||||
147 | - re-allocation of tax impact on intercompany dividends and other special items | 64 | (12 | ) | |||||
(965 | ) | - taxes on special items of operating profit | (607 | ) | (479 | ) | |||
(442 | ) | Total special items of net profit | (1,173 | ) | 1,941 | ||||
pertaining to: | |||||||||
- non-controlling interest | (5 | ) | 533 | ||||||
(442 | ) | - Eni's shareholders | (1,168 | ) | 1,408 |
- 27 -
Group results for the year / Financial review Eni in 2014
| Summarized Group balance sheet
The summarized Group balance sheet aggregates the amount of assets and liabilities derived from the statutory balance sheet in accordance with functional criteria which consider the enterprise conventionally divided into the three fundamental areas focusing on resource investments, operations and financing. Management believes that this summarized Group balance sheet is useful | information in assisting investors to assess Enis capital structure and to analyze its sources of funds and investments in fixed assets and working capital. Management uses the summarized Group balance sheet to calculate key ratios such as the proportion of net borrowings to shareholders equity (leverage) intended to evaluate whether Enis financing structure is sound and well-balanced. |
(euro million) | December 31, 2013 | December 31, 2014 | Change |
Fixed assets | |||||||||
Property, plant and equipment | 63,763 | 71,962 | 8,199 | ||||||
Inventories - Compulsory stock | 2,573 | 1,581 | (992 | ) | |||||
Intangible assets | 3,876 | 3,645 | (231 | ) | |||||
Equity-accounted investments and other investments | 6,180 | 5,130 | (1,050 | ) | |||||
Receivables and securities held for operating purposes | 1,339 | 1,861 | 522 | ||||||
Net payables related to capital expenditure | (1,255 | ) | (1,971 | ) | (716 | ) | |||
76,476 | 82,208 | 5,732 | |||||||
Net working capital | |||||||||
Inventories | 7,939 | 7,555 | (384 | ) | |||||
Trade receivables | 21,212 | 19,709 | (1,503 | ) | |||||
Trade payables | (15,584 | ) | (15,015 | ) | 569 | ||||
Tax payables and provisions for net deferred tax liabilities | (3,062 | ) | (1,865 | ) | 1,197 | ||||
Provisions | (13,120 | ) | (15,898 | ) | (2,778 | ) | |||
Other current assets and liabilities | 1,274 | 222 | (1,052 | ) | |||||
(1,341 | ) | (5,292 | ) | (3,951 | ) | ||||
Provisions for employee post-retirement benefits | (1,279 | ) | (1,313 | ) | (34 | ) | |||
Assets held for sale including related liabilities | 2,156 | 291 | (1,865 | ) | |||||
CAPITAL EMPLOYED, NET | 76,012 | 75,894 | (118 | ) | |||||
Eni shareholders' equity | 58,210 | 59,754 | 1,544 | ||||||
Non-controlling interest | 2,839 | 2,455 | (384 | ) | |||||
Shareholders equity | 61,049 | 62,209 | 1,160 | ||||||
Net borrowings | 14,963 | 13,685 | (1,278 | ) | |||||
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY | 76,012 | 75,894 | (118 | ) |
The summarized Group balance
sheet was affected by a sharp movement in the EUR/USD
exchange rate which determined an increase in net capital
employed, net borrowings and total equity of euro 5,145
million, euro 137 million and euro 5,008 million
respectively following translation of the financial
statements of US-denominated subsidiaries reflecting a
12% appreciation of the US dollar (1 EUR = 1.214 USD at
December 31, 2014 compared to 1.379 at December 31,
2013). Fixed assets amounted to euro 82,208 million, representing an increase of euro 5,732 million from December 31, 2013. The increase was attributable to favorable currency movements, capital expenditure (euro 12,240 million), upward revisions of the previous decommissioning provisions in the Exploration & Production segment mainly combine with a benign interest rate environment allowing an increase of euro 2,112 million. These increases were partly offset by the depreciation, depletion, amortization and impairment charges (euro 11,499 million), the reduction in the line item "Equity-accounted investments and other investments" (down by euro 1,051 million) due to the divestment of Enis interest in Galp and the fair value evaluation of the residual interest, the sale of other |
interests (South Stream and
EnBw), as well as the decrease in the compulsory
inventories reflecting lower commodity prices (euro 992
million). Net working capital (negative euro 5,292 million) reported a decrease of euro 3,951 million. This reflected lower "Other current assets and liabilities" (down by euro 1,052 million) following the reduction of net receivables vs. joint venture partners in the Exploration & Production segment, and decreased deferred costs related to pre-paid gas volumes provided by take-or-pay obligations due to volume makeup in the year as a result of contract renegotiations. Also lower inventories of crude oil and products (down by euro 384 million) were recorded due to the alignment to current prices. The balance of trade receivables and trade payables declined by euro 934 million mainly in the Exploration & Production segment. Finally, lower tax payables and provisions for deferred taxes were recorded due to the recognition of the above mentioned tax gain on Libyan tax by the parent company Eni SpA, net of the amount already collected in the fourth quarter, and as taxes paid were larger than those accrued in the full year due to a lowered taxable profit. These were partly offset by the write-off of deferred tax assets of Italian subsidiaries for euro 976 million. |
- 28 -
Group results for the year / Financial review Eni in 2014
Shareholders equity
including non-controlling interest was euro 62,209
million, representing an increase of euro 1,160 million
from December 31, 2013. This was due to comprehensive
income for the year (euro 5,598 million) as a result of
net profit (euro 850 million), positive foreign currency
effects (euro 5,008 million), net of negative changes in
the cash flow hedge reserve (euro 167 million), and of
the reversal of the fair-value reserve recorded in equity
on Galp interest due to the divestment. This addition to
equity was partly offset by dividend payments to
Enis shareholders and other changes of euro 4,438
million (dividend to Enis shareholders of euro
4,006 million, of which euro 2,020 million related to the
interim dividend for fiscal year 2014, share repurchases
amounting to euro 380 million and dividends paid to
non-controlling interest). Net
borrowings and leverage |
related to operations,
including among others non-operating financing
receivables and securities not related to operations.
Non-operating financing receivables consist of amounts
due to Enis financing subsidiaries from banks and
other financing institutions and amounts due to other
subsidiaries from banks for investing purposes and
deposits in escrow. Securities not related to operations
consist primarily of government and corporate securities. Leverage is a measure used by management to assess the Companys level of indebtedness. It is calculated as a ratio of net borrowings which is calculated by excluding cash and cash equivalents and certain very liquid assets from financial debt to shareholders equity, including non-controlling interest. Management periodically reviews leverage in order to assess the soundness and efficiency of the Group balance sheet in terms of optimal mix between net borrowings and net equity, and to carry out benchmark analysis with industry standards. |
(euro million) | December 31, 2013 | December 31, 2014 | Change |
Total debt: | 25,560 | 25,891 | 331 | ||||||
- short-term debt | 4,685 | 6,575 | 1,890 | ||||||
- long-term debt | 20,875 | 19,316 | (1,559 | ) | |||||
Cash and cash equivalents | (5,431 | ) | (6,614 | ) | (1,183 | ) | |||
Securities held for trading and other securities held for non-operating purposes | (5,037 | ) | (5,037 | ) | |||||
Financing receivables for non-operating purposes | (129 | ) | (555 | ) | (426 | ) | |||
Net borrowings | 14,963 | 13,685 | (1,278 | ) | |||||
Shareholders' equity including non-controlling interest | 61,049 | 62,209 | 1,160 | ||||||
Leverage | 0.25 | 0.22 | (0.03 | ) |
- 29 -
Group results for the year / Financial review Eni in 2014
| Summarized Group cash flow statement and Change in net borrowings
Enis summarized Group cash flow statement derives from the statutory statement of cash flows. It enables investors to understand the link existing between changes in cash and cash equivalents (deriving from the statutory cash flows statement) and in net borrowings (deriving from the summarized cash flow statement) that occurred from the beginning of the period to the end of period. The measure enabling such a link is represented by the free cash flow which is the cash in excess of capital expenditure needs. Starting from free cash flow it is possible to determine either: (i) changes in cash and cash equivalents for | the period by adding/deducting cash flows relating to financing debts/receivables (issuance/repayment of debt and receivables related to financing activities), shareholders equity (dividends paid, net repurchase of own shares, capital issuance) and the effect of changes in consolidation and of exchange rate differences; and (ii) change in net borrowings for the period by adding/deducting cash flows relating to shareholders equity and the effect of changes in consolidation and of exchange rate differences. The free cash flow is a non-GAAP measure of financial performance. |
2012 | (euro million) | 2013 | 2014 | Change |
4,947 | Net profit - continuing operations | 4,959 | 850 | (4,109 | ) | |||||||
Adjustments to reconcile net profit to net cash provided by operating activities: | ||||||||||||
11,501 | - depreciation, depletion and amortization and other non-monetary items | 9,723 | 12,131 | 2,408 | ||||||||
(875 | ) | - net gains on disposal of assets | (3,770 | ) | (95 | ) | 3,675 | |||||
11,962 | - dividends, interests, taxes and other changes | 9,174 | 6,655 | (2,519 | ) | |||||||
(3,281 | ) | Changes in working capital related to operations | 456 | 2,668 | 2,212 | |||||||
(11,702 | ) | Dividends received, taxes paid, interest (paid) received during the period | (9,516 | ) | (7,099 | ) | 2,417 | |||||
12,552 | Net cash provided by operating activities - continuing operations | 11,026 | 15,110 | 4,084 | ||||||||
15 | Net cash provided by operating activities - discontinued operations | |||||||||||
12,567 | Net cash provided by operating activities | 11,026 | 15,110 | 4,084 | ||||||||
(12,805 | ) | Capital expenditure - continuing operations | (12,800 | ) | (12,240 | ) | 560 | |||||
(756 | ) | Capital expenditure - discontinued operations | ||||||||||
(13,561 | ) | Capital expenditure | (12,800 | ) | (12,240 | ) | 560 | |||||
(569 | ) | Investments and purchase of consolidated subsidiaries and businesses | (317 | ) | (408 | ) | (91 | ) | ||||
6,025 | Disposals | 6,360 | 3,684 | (2,676 | ) | |||||||
(193 | ) | Other cash flow related to capital expenditure, investments and disposals | (243 | ) | 435 | 678 | ||||||
4,269 | Free cash flow | 4,026 | 6,581 | 2,555 | ||||||||
(79 | ) | Borrowings (repayment) of debt related to financing activities | (3,981 | ) | (414 | ) | 3,567 | |||||
5,814 | Changes in short and long-term financial debt | 1,715 | (628 | ) | (2,343 | ) | ||||||
(3,743 | ) | Dividends paid and changes in non-controlling interests and reserves | (4,225 | ) | (4,434 | ) | (209 | ) | ||||
(16 | ) | Effect of changes in consolidation and exchange differences | (40 | ) | 78 | 118 | ||||||
6,245 | NET CASH FLOW | (2,505 | ) | 1,183 | 3,688 |
Change in net borrowings
2012 | (euro million) | 2013 | 2014 | Change |
4,269 | Free cash flow | 4,026 | 6,581 | 2,555 | ||||||||
(2 | ) | Net borrowings of acquired companies | (21 | ) | (19 | ) | 2 | |||||
12,446 | Net borrowings of divested companies | (23 | ) | 23 | ||||||||
(345 | ) | Exchange differences on net borrowings and other changes | 349 | (850 | ) | (1,199 | ) | |||||
(3,743 | ) | Dividends paid and changes in non-controlling interest and reserves | (4,225 | ) | (4,434 | ) | (209 | ) | ||||
12,625 | CHANGE IN NET BORROWINGS | 106 | 1,278 | 1,172 |
- 30 -
Group results for the year / Financial review Eni in 2014
Consolidated profit and loss account | |||
2012 | (euro million) | 2013 | 2014 |
REVENUES | ||||||||||
127,109 | Net sales from operations | 114,697 | 109,847 | |||||||
1,548 | Other income and revenues | 1,387 | 1,101 | |||||||
128,657 | 116,084 | 110,948 | ||||||||
OPERATING EXPENSES | ||||||||||
95,034 | Purchases, service and other | 90,003 | 86,340 | |||||||
4,640 | Payroll and related costs | 5,301 | 5,337 | |||||||
(158 | ) | OTHER OPERATING (EXPENSE) INCOME | (71 | ) | 145 | |||||
13,617 | DEPRECIATION, DEPLETION, AMORTIZATION AND IMPAIRMENTS | 11,821 | 11,499 | |||||||
15,208 | OPERATING PROFIT | 8,888 | 7,917 | |||||||
FINANCE INCOME (EXPENSE) | ||||||||||
7,208 | Finance income | 5,732 | 6,459 | |||||||
(8,327 | ) | Finance expense | (6,653 | ) | (7,710 | ) | ||||
Finance income (expense) from financial instruments held for trading, net | 4 | 24 | ||||||||
(252 | ) | Derivative financial instruments | (92 | ) | 162 | |||||
(1,371 | ) | (1,009 | ) | (1,065 | ) | |||||
INCOME (EXPENSE) FROM INVESTMENTS | ||||||||||
186 | Share of profit (loss) of equity-accounted investments | 222 | 121 | |||||||
2,603 | Other gain (loss) from investments | 5,863 | 369 | |||||||
- of which gain on the divestment of the 28.57% stake in Eni East Africa | 3,359 | |||||||||
2,789 | 6,085 | 490 | ||||||||
16,626 | PROFIT BEFORE INCOME TAXES | 13,964 | 7,342 | |||||||
(11,679 | ) | Income taxes | (9,005 | ) | (6,492 | ) | ||||
4,947 | Net profit - continuing operations | 4,959 | 850 | |||||||
3,732 | Net profit (loss) - discontinued operations | |||||||||
8,679 | Net profit | 4,959 | 850 | |||||||
Attributable to: | ||||||||||
Enis shareholders | ||||||||||
4,200 | - continuing operations | 5,160 | 1,291 | |||||||
3,590 | - discontinued operations | |||||||||
7,790 | 5,160 | 1,291 | ||||||||
Non-controlling interest | ||||||||||
747 | - continuing operations | (201 | ) | (441 | ) | |||||
142 | - discontinued operations | |||||||||
889 | (201 | ) | (441 | ) |
- 31 -
Group results for the year / Financial review Eni in 2014
Consolidated balance sheet | ||
(euro million) | December 31, 2013 | December 31, 2014 |
ASSETS | |||||||
Current assets | |||||||
Cash and cash equivalents | 5,431 | 6,614 | |||||
Other financial activities held for trading | 5,004 | 5,024 | |||||
Other financial assets held for trading or available for sale | 235 | 257 | |||||
Trade and other receivables | 28,890 | 28,601 | |||||
Inventories | 7,939 | 7,555 | |||||
Current tax assets | 802 | 762 | |||||
Other current tax assets | 835 | 1,209 | |||||
Other current assets | 1,325 | 4,385 | |||||
50,461 | 54,407 | ||||||
Non-current assets | |||||||
Property, plant and equipment | 63,763 | 71,962 | |||||
Inventory - Compulsory stock | 2,573 | 1,581 | |||||
Intangible assets | 3,876 | 3,645 | |||||
Equity-accounted investments | 3,153 | 3,115 | |||||
Other investments | 3,027 | 2,015 | |||||
Other financial assets | 858 | 1,022 | |||||
Deferred tax assets | 4,658 | 5,231 | |||||
Other non-current receivables | 3,676 | 2,773 | |||||
85,584 | 91,344 | ||||||
Assets held for sale | 2,296 | 456 | |||||
TOTAL ASSETS | 138,341 | 146,207 | |||||
LIABILITIES AND SHAREHOLDERS EQUITY | |||||||
Current liabilities | |||||||
Short-term debt | 2,553 | 2,716 | |||||
Current portion of long-term debt | 2,132 | 3,859 | |||||
Trade and other payables | 23,701 | 23,703 | |||||
Income taxes payables | 755 | 534 | |||||
Other taxes payables | 2,291 | 1,873 | |||||
Other current liabilities | 1,437 | 4,489 | |||||
32,869 | 37,174 | ||||||
Non-current liabilities | |||||||
Long-term debt | 20,875 | 19,316 | |||||
Provisions for contingencies | 13,120 | 15,898 | |||||
Provisions for employee benefits | 1,279 | 1,313 | |||||
Deferred tax liabilities | 6,750 | 7,847 | |||||
Other non-current liabilities | 2,259 | 2,285 | |||||
44,283 | 46,659 | ||||||
Liabilities directly associated with assets held for sale | 140 | 165 | |||||
TOTAL LIABILITIES | 77,292 | 83,998 | |||||
SHAREHOLDERS EQUITY | |||||||
Non-controlling interest | 2,839 | 2,455 | |||||
Eni shareholders equity | |||||||
Share capital | 4,005 | 4,005 | |||||
Reserves related to the fair value of cash flow hedging derivatives net of tax effect | (154 | ) | (284 | ) | |||
Other reserves | 51,393 | 57,343 | |||||
Treasury shares | (201 | ) | (581 | ) | |||
Interim dividend | (1,993 | ) | (2,020 | ) | |||
Net profit | 5,160 | 1,291 | |||||
Total Eni shareholders equity | 58,210 | 59,754 | |||||
TOTAL SHAREHOLDERS EQUITY | 61,049 | 62,209 | |||||
TOTAL LIABILITIES AND SHAREHOLDERS EQUITY | 138,341 | 146,207 |
- 32 -
Group results for the year / Financial review Eni in 2014
Consolidated statement of cash flow | |||
2012 | (euro million) | 2013 | 2014 |
4,947 | Net profit of the year - continuing operations | 4,959 | 850 | |||||||
Adjustments to reconcile net profit to net cash provided by operating activities: | ||||||||||
9,645 | Depreciation and amortization | 9,421 | 9,970 | |||||||
3,972 | Impairments of tangible and intangible assets, net | 2,400 | 1,529 | |||||||
(186 | ) | Share of (profit) loss of equity-accounted investments | (222 | ) | (121 | ) | ||||
(875 | ) | Gain on disposal of assets, net | (3,770 | ) | (95 | ) | ||||
(431 | ) | Dividend income | (400 | ) | (385 | ) | ||||
(94 | ) | Interest income | (142 | ) | (171 | ) | ||||
808 | Interest expense | 711 | 719 | |||||||
11,679 | Income taxes | 9,005 | 6,492 | |||||||
(1,947 | ) | Other changes | (1,882 | ) | 744 | |||||
Changes in working capital: | ||||||||||
(1,402 | ) | - inventories | 350 | 1,524 | ||||||
(3,161 | ) | - trade receivables | (1,379 | ) | 2,344 | |||||
2,014 | - trade payables | 703 | (1,253 | ) | ||||||
329 | - provisions for contingencies | 59 | (187 | ) | ||||||
(1,061 | ) | - other assets and liabilities | 723 | 240 | ||||||
(3,281 | ) | Cash flow from changes in working capital | 456 | 2,668 | ||||||
17 | Net change in the provisions for employee benefits | 6 | 9 | |||||||
930 | Dividends received | 630 | 612 | |||||||
79 | Interest received | 97 | 112 | |||||||
(829 | ) | Interest paid | (942 | ) | (882 | ) | ||||
(11,882 | ) | Income taxes paid, net of tax receivables received | (9,301 | ) | (6,941 | ) | ||||
12,552 | Net cash provided by operating activities - continuing operations | 11,026 | 15,110 | |||||||
15 | Net cash provided by operating activities - discontinued operations | |||||||||
12,567 | Net cash provided by operating activities | 11,026 | 15,110 | |||||||
Investing activities: | ||||||||||
(11,267 | ) | - tangible assets | (10,913 | ) | (10,685 | ) | ||||
(2,294 | ) | - intangible assets | (1,887 | ) | (1,555 | ) | ||||
(178 | ) | - consolidated subsidiaries and businesses | (25 | ) | (36 | ) | ||||
(391 | ) | - investments | (292 | ) | (372 | ) | ||||
(17 | ) | - securities | (5,048 | ) | (77 | ) | ||||
(1,542 | ) | - financing receivables | (978 | ) | (1,289 | ) | ||||
54 | - change in payables and receivables in relation to investing activities and capitalized depreciation | 50 | 669 | |||||||
(15,635 | ) | Cash flow from investing activities | (19,093 | ) | (13,345 | ) | ||||
Disposals: | ||||||||||
1,240 | - tangible assets | 514 | 97 | |||||||
61 | - intangible assets | 16 | 8 | |||||||
3,521 | - consolidated subsidiaries and businesses | 3,401 | ||||||||
1,203 | - investments | 2,429 | 3,579 | |||||||
54 | - securities | 36 | 57 | |||||||
1,431 | - financing receivables | 1,561 | 506 | |||||||
(252 | ) | - change in payables and receivables in relation to disposals | 155 | 155 | ||||||
7,258 | Cash flow from disposals | 8,112 | 4,402 | |||||||
(8,377 | ) | Net cash used in investing activities | (10,981 | ) | (8,943 | ) | ||||
10,506 | Proceeds from long-term debt | 5,418 | 1,916 | |||||||
(3,961 | ) | Repayments of long-term debt | (4,720 | ) | (2,751 | ) | ||||
(731 | ) | Increase (decrease) in short-term debt | 1,017 | 207 | ||||||
5,814 | 1,715 | (628 | ) | |||||||
Net capital contributions by non-controlling interest | 1 | 1 | ||||||||
Sale of treasury shares | ||||||||||
29 | Net acquisition of treasury shares different from Eni SpA | 1 | ||||||||
604 | Acquisition of additional interests in consolidated subsidiaries | (28 | ) | |||||||
(3,840 | ) | Dividends paid to Enis shareholders | (3,949 | ) | (4,006 | ) | ||||
(536 | ) | Dividends paid to non-controlling interest | (250 | ) | (49 | ) | ||||
Acquisition of treasury shares | (380 | ) | ||||||||
2,071 | Net cash used in financing activities | (2,510 | ) | (5,062 | ) | |||||
(93 | ) | - of which with related parties | 119 | (99 | ) | |||||
(4 | ) | Effect of change in consolidation (inclusion/exclusion of significant/insignificant subsidiaries) | 2 | 2 | ||||||
(12 | ) | Effect of exchange rate changes on cash and cash equivalents and other changes | (42 | ) | 76 | |||||
6,245 | Net cash flow of the year | (2,505 | ) | 1,183 | ||||||
1,691 | Cash and cash equivalents - beginning of the year | 7,936 | 5,431 | |||||||
7,936 | Cash and cash equivalents - end of the year | 5,431 | 6,614 |
- 33 -
Directors and officers Eni in 2014
- 34 -
Directors and officers Eni in 2014
Remuneration* The Eni Remuneration Policy is defined consistently with the recommendations of the Borsa Italiana Code as transposed in the Eni Code. It is approved by the Board of Directors following a proposal by the Compensation Committee, entirely made up of non-executive, independent Directors, and it is defined in accordance with the governance model adopted by the Company and with the recommendations of the Corporate Governance Code. |
This Policy aims to align the interests of management with the prime objective of creating sustainable value for shareholders over the medium-long term, in accordance with the guidelines defined in the Strategic Plan of the Company. The table describes the main elements of the approved 2015 Guidelines for the remuneration of the Chief Executive Officer, of the Chief Operating Officers of Enis Divisions and other Managers with strategic responsibilities (MSR). | |
Remuneration Policy 2015 | |||
Component | Purpose and characteristics | Conditions for the implementation | Values |
Fixed remuneration | - Values the expertise, experience and contribution required by the assigned role | - Setting of the remuneration levels through benchmarks consistent with the characteristics of Eni and the assigned roles | -
CEO/GM: euro 1,350,000 per year - MSR: remuneration set based on the assigned role with possible adjustments in relation to annual competitive positioning (median market values) settings |
AVI - Annual Variable Incentive | -
Promotes the achievement of the annual budget targets,
also defined in terms of sustainability in the medium to
long term - Beneficiaries: all managerial resources |
2015
CEO/GM targets: 1. Economic and financial results (25%) - EBT - Free cash flow 2. Operating results and sustainability of economic results (25%) - Hydrocarbon production - Reserve replacement rate 3. Environmental sustainability and human capital (25%) - CO2 emissions - accident frequency rate 4. Efficiency and financial strength (25%) - ROACE - Debt/EBITDA - MSR targets: business and individual targets base on those of the CEO/GM and the assigned responsibilities - Incentives paid on the basis of the results achieved in the previous year and evaluated according to a performance scale 70÷130 points (1), with a minimum threshold for the incentive equal to an overall performance of 85 points - Clawback in cases of manifestly wrong or fraudulently altered data and violation of laws and regulations, of the Code of Ethics or of Company rules |
-
CEO/GM: level of target incentive equal to 100% of the
fixed remuneration (min 85% and max 130%) - MSR: levels of incentive targets differentiated according to the assigned role, up to a maximum of 60% of the fixed remuneration |
DMI - Deferred Monetary Incentive | -
Promotes the achievement of annual targets and
profitability growth of the business in the long term - Beneficiaries: managerial resources who have achieved their annual targets |
-
Target gate: achieving the performance level required for
the payment of the annual bonus - EBT performance measured relative to the value of the Planned EBT - Incentives assigned, in the event of achievement of individual targets, based on the EBT results achieved in the previous year, rated on a performance scale of 70÷130 (1) - Incentives paid as a variable percentage between zero and 170% of the assigned amounts, according to the average of the EBT annual results achieved during the vesting period, rated on an annual performance scale of 70÷170 (1) - Three-year vesting - Clawback in cases of manifestly wrong or fraudulently altered data and violation of laws and regulations, of the Code of Ethics or of Company rules |
-
CEO/GM: incentive to be assigned for targets equal to
49.2% of the fixed remuneration (min 34.4% and max 64%) - MSR: incentives awarded based on targets differentiated according to the assigned role, up to a maximum of 40% of the fixed remuneration |
LTMI - Long Term Monetary Incentive | -
Promotes the alignment with shareholder interests and the
sustainability of value creation in the long term - Beneficiaries: Managerial Resources Critical for the Business (4) |
-
Performance measured in terms of variation of the TSR
parameters (2) (60%) and Net Present Value of
proved reserves(40%), compared to the variation achieved
by the companies of a peer group of reference (Exxon,
Chevron, Shell, BP, Total, Repsol) - Incentives paid as a percentage varying between zero and 130% of the amounts assigned, according to the average of the annual positioning achieved during the vesting period (3) - Three-year vesting - Clawback in cases of manifestly wrong or fraudulently altered data and violation of laws and regulations, of the Code of Ethics or of Company rules |
-
CEO/GM: incentive to be assigned for targets equal to
100% of the fixed remuneration - MSR: incentives awarded based on targets differentiated according to the assigned role, up to a maximum of 75% of the fixed remuneration |
Benefits | -
Supplementing the salary package following a total reward
logic by means of predominantly social security and
welfare benefits - Beneficiaries: all managerial resources |
- Conditions defined by the national collective labor agreements and the complementary company agreements applicable to senior managers | -
Supplementary pension - Supplementary health care - Insurance coverage - Car for business and personal use |
Severance Payments | - Severance payments to protect the Company also from potential competitive risks | - CEO/GM: additional severance indemnity: non-renewal of the mandate or early termination of the same, except for termination with just cause and resignations not caused by a reduction of powers; non-competition agreement: activated at the discretion of the BoD at the time of termination of the employment relationship (5) | - CEO/GM: supplementary severance indemnities: equal to two years annual fixed remuneration (euro 2,700,000); consideration of the non-competition agreement (in case of exercise of the option): ranging from a minimum of euro 1,500,000 to a maximum of euro 2,250,000, depending on the average annual performance achieved in the previous three years |
(1) Performance rated below the minimum threshold (70 points) is considered equal to zero. (2) The Total Shareholder Return measures the overall return of a stock investment, taking into consideration both the price change and the dividends paid and reinvested in the same stock, in a specific period. The Net Present Value of proved reserves represents the present value of the future cash flows of proved reserves, net of future production and development costs and related taxes. It is calculated on the basis of standard references defined by the Securities Exchange Commission on the basis of the data published by oil companies in the official documentation (Form 10-K and Form 20-F). (3) The minimum incentive threshold involves reaching 5th place for both indicators in at least one year of the three-year vesting period. (4) The executives of Eni and its subsidiaries identified during the annual implementation of the Plan among those who occupy the positions that are most directly responsible for the business performance or that are of strategic interest and who, at the date of assignment, are employees and/or in service at Eni SpA and its subsidiaries, including Eni Managers with strategic responsibilities. (5) A consideration of euro 500,000 is provided for the BoDs stock option. |
(*) For detailed information on Enis remuneration policy and compensation see the "Remuneration Report 2015" available on Enis website under the sections "Governance" and "Investor relations". |
- 35 -
Directors and officers Eni in 2014
The following table lists the individual remunerations to the Directors, Statutory Auditors, General Managers and, in aggregate, to the other Managers with strategic responsibilities. The remunerations received from subsidiaries and/or affiliates, | except those waived or paid to the Company, are shown separately. All parties who filled these roles during the period are included, even if they only held office for a fraction of the year. |
Remuneration paid to Directors, Statutory Auditors, Chief Operating Officers, and other Managers with strategic responsibilities | ||||||||||||
(euro thousand)
|
Position |
Period for
which the position was held |
Expiration
of the office (*) |
Fixed
remuneration |
Remuneration
for participation in the Committees |
Variable
non-equity remuneration |
Benefits in
kind |
Other
remuneration |
Total |
Fair value
of equity compensation |
Severance
indemnity for end of office or termination of employment |
|
Bonuses and
other incentives |
Profit sharing |
Board of Directors | |||||||||||||||||||||||||
Giuseppe Recchi | Chairman | 01.01 - 05.08 | 05.2014 | 272 | 342 | 4 | 618 | ||||||||||||||||||
Emma Marcegaglia | Chairman | 05.08 - 12.31 | 05.2017 | 154 | 154 | ||||||||||||||||||||
Paolo Scaroni | CEO and General Manager | 01.01 - 05.08 | 05.2014 | 505 | 2,696 | 8 | 3,209 | 8,361 | |||||||||||||||||
Claudio Descalzi | CEO and General Manager | 05.09 - 12.31 | 05.2017 | 874 | 9 | 500 | 1,383 | ||||||||||||||||||
COO Division E&P (**) | 01.01 - 05.08 | 273 | 1,218 | 4 | 479 | 1,974 | |||||||||||||||||||
Total | 1,147 | 1,218 | 13 | 979 | 3,357 | ||||||||||||||||||||
Former Directors | 01.01 - 05.08 | 05.2014 | 246 | 98 | 344 | ||||||||||||||||||||
Directors in charge | 05.08 - 12.31 | 05.2017 | 404 | 265 | 669 | ||||||||||||||||||||
Board of Statutory Auditors | 384 | 384 | |||||||||||||||||||||||
Chief Operating Officers | |||||||||||||||||||||||||
Angelo Fanelli | Division R&M | 01.01 - 06.30 | 300 | 396 | 7 | 703 |
Other executives with strategic responsibilities (***) | Remuneration in the company that prepares the Financial Statements | 5,945 | 5,777 | 161 | 120 | 12,003 | 4,990 | ||||||||||||||
Remuneration from subsidiaries and associates | 737 | 115 | 261 | 47 | 1,160 | ||||||||||||||||
Total | 6,682 | 5,892 | 422 | 167 | 13,163 | 4,990 | |||||||||||||||
10,094 | 363 | 10,544 | 454 | 1,146 | 22,601 | 13,351 |
(*) The term
of office expires with the Shareholders Meeting
approving the Financial Statements for the year ending
December 31, 2016. (**) The position of COO E&P Division has been covered ad interim from May 9 to June 30, 2014 without any remuneration. (***) Managers who were permanent members of the Company's Management Committee, during the course of the year together with the Chief Executive Officer and Division Chief Operating Officers, or who reported directly to the Chief Executive Officer (twenty managers). |
In particular:
- the column "Fixed Remuneration" reports the
fixed remuneration and fixed salary from employment due for the
year, gross of the social security contribution and tax expenses
to be paid by the employee; it excludes attendance fees, as these
are not provided for. Any indemnities or payments with reference
to the employment relationship are indicated separately;
- the "Committee membership remuneration" column
reports the compensation due to the Directors for participation
in the Committees established by the Board;
- the column "Variable non-equity remuneration"
under the item "Bonuses and other incentives" shows the
incentives paid during the year due to rights vested following
the assessment and approval of the related performance results by
the relevant corporate bodies, in accordance with that specified,
in greater detail, in the Table "Monetary incentive plans
for Directors, General Managers, and other Managers with
strategic responsibilities"; the column "Profit
sharing" does not show any figures since there are no
provisions for profit sharing;
- the "Non-monetary benefits" column reports the
value of the fringe benefits awarded;
- the "Other remuneration" column reports any
other remuneration deriving from other services provided;
- the "Fair value of equity remunerations"
column reports the relevant fair value for the year related to
the existing stock option plans, estimated in accordance with
international accounting standards, which assign the related cost
in the vesting period; and
- the "Severance indemnities for end of office or
termination of employment" column reports the
indemnities accrued, even if not yet paid, for the terminations
which occurred during the course of the financial year in
question, or in relation to the end of the mandate and/or
employment.
- 36 -
Directors and officers Eni in 2014
Monetary incentive plans for Directors, General Managers, and other Managers with strategic responsibilities | ||||||||
(euro thousand)
|
Position |
|
|
|
||||
|
|
|
|
|
|
Giuseppe Recchi | Chairman until 05.08.2014 | 342 | |||||||||||||||
Paolo Scaroni | Chief Executive Officer and General Manager until 05.08.2014 | 1,831 | 551 | three-year | 2,447 | 865 | 6,189 | ||||||||||
Claudio Descalzi | Chief Executive Officer and General Manager since 05.09.2014 | 1,350 | three-year | ||||||||||||||
COO E&P Division until 05.08.2014 | 879 | 378 | 363 | 339 | 1,868 | ||||||||||||
Angelo Fanelli | COO R&M Division until 06.30.2014 | 396 | 985 | ||||||||||||||
Other Managers with strategic responsibilities (2) | 3,168 | 4,587 | 3,074 | 2,464 | 8,000 | 260 | |||||||||||
6,616 | 6,866 | 5,884 | 3,668 | 17,042 | 260 |
(1) Payment
relating to the Deferred Monetary Incentive awarded in
2011. (2) Managers who were permanent members of the Company's Management Committee, during the course of the year together with the Chief Executive Officer and Division Chief Operating Officers, or who reported directly to the Chief Executive Officer (twenty managers). |
Overall remuneration of key
management personnel Remuneration of persons responsible of key positions in planning, direction and control functions of Eni Group companies, including executive and non-executive Directors, Chief Operating Officers and other Managers with strategic responsibilities in charge at December 31, 2014, amounted to euro 43 million, as described in the following table. Pay-mix |
- 37 -
Investor information Eni in 2014
Investor information
Eni share performance in 2014 In accordance with Article 5 of the By-laws, the Companys share capital amounts to euro 4,005,358,876.00, fully-paid, and is represented by 3,634,185,330 ordinary registered shares without indication of par value. In the last session of 2014, the Eni share price, quoted on the Italian Stock Exchange, was euro 14.51, down by 17 percentage points from the price quoted at the end of 2013 (euro 17.49). The Italian Stock Exchange is the primary market where the Eni share is traded. During the year the FTSE/MIB index, the basket including the 40 most important shares listed on the Italian Stock Exchange, was barely unchanged (up by 0.2 percentage points). At the end of |
2014, the Eni ADR listed on
the NYSE was $34.91, down 28.1% compared to the price
registered in the last session of 2013 ($48.49). One ADR
is equal to two Eni ordinary shares. In the same period
the S&P 500 index increased by 11.4 percentage
points. Eni market capitalization at the end of 2014 was
euro 52.4 billion (euro 63.4 billion at the end of 2013),
confirming Eni as the first company for market
capitalization listed on the Italian Stock Exchange. Shares traded during the year totaled almost 4.4 billion, with a daily average of shares traded of 17.2 million (15.4 million in 2013). The total trade value of Eni shares amounted to approximately euro 77 billion (euro 68 billion in 2013), equal to a daily average of euro 304 million. |
Share information | |||
2012 | 2013 | 2014 |
Market quotations for common stock on the Mercato Telematico Azionario (MTA) | |||||||||
High | (euro) | 18.70 | 19.48 | 20.41 | |||||
Low | 15.25 | 15.29 | 23.29 | ||||||
Average daily close | 17.18 | 17.57 | 17.83 | ||||||
Year-end close | 18.34 | 17.49 | 14.51 | ||||||
Market quotations for ADR on the New York Stock Exchange | |||||||||
High | (US$) | 49.44 | 52.12 | 55.30 | |||||
Low | 36.85 | 40.39 | 32.81 | ||||||
Average daily close | 44.24 | 46.68 | 47.37 | ||||||
Year-end close | 49.14 | 48.49 | 34.91 | ||||||
Average daily traded volumes | (million of shares) | 15.63 | 15.44 | 17.21 | |||||
Value of traded volumes | (euro million) | 267.0 | 271.4 | 304.0 | |||||
- 38 -
Investor information Eni in 2014
Summary financial data | |||
2012 | 2013 | 2014 |
Net profit | ||||||||||
- per share (a) | (euro) | 1.16 | 1.42 | 0.36 | ||||||
- per ADR (a) (b) | (US$) | 2.98 | 3.77 | 0.96 | ||||||
Adjusted net profit | ||||||||||
- per share (a) | (euro) | 1.97 | 1.22 | 1.03 | ||||||
- per ADR (a) (b) | (US$) | 5.06 | 3.24 | 2.74 | ||||||
Leverage | 0.47 | 0.25 | 0.22 | |||||||
Coverage | 11.3 | 8.8 | 7.4 | |||||||
Current ratio | 1.4 | 1.5 | 1.5 | |||||||
Debt coverage | 83.4 | 73.7 | 110.4 | |||||||
Dividend pertaining to the year | (euro per share) | 1.08 | 1.10 | 1.12 | ||||||
Pay-out | (%) | 50 | 77 | 311 | ||||||
Dividend yield (c) | (%) | 5.9 | 6.5 | 7.6 | ||||||
TSR | 22.0 | 1.3 | (11.9 | ) | ||||||
(a) Fully
diluted. Ratio of net profit and average number of shares
outstanding in the year. Dollar amounts are converted on
the basis of the average EUR/USD exchange rate quoted by
ECB for the year presented. (b) One American Depositary Receipt (ADR) is equal two Eni ordinary shares. (c) Ratio of dividend for the period and the average price of Eni shares as recorded in December. |
| Dividends Management intends to propose to the Annual Shareholders Meeting scheduled on May 13, 2015, the distribution of a dividend of euro 1.12 per share for fiscal year 2014, of which euro 0.56 was already paid as interim dividend in September 2014. Total cash outlay for the 2014 dividend is expected at approximately euro 4.01 billion (including euro 1.99 billion already paid in September 2014) if the Annual Shareholders Meeting approves the annual dividend. In future years, management |
expects to continue paying interim dividends for each fiscal year, with the balance to the full-year dividend to be paid in each following year. Eni intends to continue paying interim dividends in the future. Holders of ADRs receive their dividends in US dollars. The rate of exchange used to determine the amount in dollars is equal to the official rate recorded on the date of dividend payment in Italy (May 22, 2014). On ADR payment date, Bank of New York Mellon pays the dividend less the amount of any withholding tax under Italian law (currently 27%) to all Depository | Trust Company Participants, representing payment of Eni SpAs gross dividend. By submitting to Bank of New York Mellon certain required documents with respect to each dividend payment, US holders of ADRs will enable the Italian Depositary bank and Bank of New York Mellon as ADR Depositary to pay the dividend at the reduced withholding tax rate of 15%. US shareholders can obtain relevant documents, as well as a complete instruction packet to benefit from this tax relief by contacting Bank of New York Mellon at 201-680-6825. |
- 39 -
Investor information Eni in 2014
- 40 -
Eni Shareholders approve 2014 Financial Statements at Annual Meeting
Rome, May 13, 2015 - The Ordinary Meeting of Enis Shareholders, held today, resolved the following: |
| to approve the financial statements at December 31, 2014 of Eni SpA which report a net profit amounting to euro 4,454,704,262.21; | |
| to allocate the net profit for the period of euro 4,454,704,262.21, of which euro 2,435,016,587.73 remains following the distribution of the 2014 interim dividend of 0.56 euro per share, resolved by the Board of Directors on September 17, 2014, as follows: |
- | the amount of euro 32,908,326.92 to the reserve required by Article 6, paragraph 1, letter a) of Legislative Decree No. 38 of February 28, 2005; | |||
- | to shareholders a dividend of euro 0.56 per share owned and outstanding at the ex-dividend date, excluding treasury shares on that date, thus completing payment of the dividend for the financial year 2014. The total dividend per share for the financial year 2014 therefore amounts to euro 1.12 per share; | |||
- | the payment of the balance of the 2014 dividend of euro 0.56, on May 20, 2015, with an ex-dividend date of May 18, 2015 and a record date of May 19, 2015. |
In addition, Enis Shareholders Meeting resolved in favor of the first section of the Remuneration report, pursuant to Article 123-ter of the Legislative Decree 58/1998.
Company Contacts:
Press Office: Tel. +39.0252031875 - +39.0659822030
Freephone for shareholders (from Italy): 800940924
Freephone for shareholders (from abroad): +800 11 22 34 56
Switchboard: +39-0659821
ufficio.stampa@eni.com
segreteriasocietaria.azionisti@eni.com
investor.relations@eni.com
Web site: www.eni.com
Eni: investigation into OPL 245 case, audit conducted by independent US law firm did not find evidence of illegal conduct
San Donato Milanese (Milan), May 31, 2015 - Regarding the pending preliminary investigation by the Italian authorities into the OPL 245 case, Eni informs that an audit conducted by an independent US law firm on behalf of Enis board of statutory auditors and watch structure, did not find evidence of illegal conduct in relation to Eni and Shells 2011 transaction with the Nigerian government for the acquisition of the OPL 245 license in Nigeria. The audits examined the documents and information available to the company or otherwise received or acquired following the start of the investigation. The final report of this audit was made available to the judiciary with whom Eni is co-operating in full. This press release is issued at the request of Consob, pursuant to Article 114 paragraph 5 of the TUF.
Company Contacts:
Press Office: Tel. +39.0252031875 - +39.0659822030
Freephone for shareholders (from Italy): 800940924
Freephone for shareholders (from abroad): +800 11 22 34 56
Switchboard: +39-0659821
ufficio.stampa@eni.com
segreteriasocietaria.azionisti@eni.com
investor.relations@eni.com
Web site: www.eni.com