1. 2008 Results and Strategy Presentation
London, 13th February 2009
2. 2008: A Very Good Year
E&P – Superior production growth: 1,797 kboe/d, +5.6% net of PSA effect
G&P – High cash generation: € 1.9 bln free cash flow
R&M – Italian market share: +140bp to 30.6%
Adjusted net profit up 7.7%
Industry-leading dividend yield
2008 total dividend at € 1.30 per share
2
3. Regulated Business Restructuring
Market
Market
~50% ~40%
50% 40%
10% share ~5% shares
SRG
SRG
buy back buy back
100%
Italgas 100% 100%
100% Italgas Stogit
Stogit
Unlock significant value for Eni’s shareholders
3
5. Regulated Business Restructuring: Transaction Terms
Sale of 100% of Italgas and Stogit to Snam Rete Gas
Total consideration: €4.7 billion, in line with RAB
Paid in cash through capital increase up to €3.5 billion and new debt up to
€ 1.3 billion
Eni’s commitment to subscribe its share of capital increase
2008 Preliminary EBITDA 2008 RAB
Mln € Bln €
~20.0
~2,300
12.8
1,511
Snam Rete Gas* New Group**
Snam Rete Gas New Group**
* SRG estimate assuming an annual inflation rate of 2% and on the basis of the current regulatory framework
5
** Proforma data: Snam Rete Gas + Stogit S.p.A.+ Italgas S.p.A. & Napoletana Gas S.p.A. (excl. other subsidiaries)
12. Sources and Uses of Cash
Billion €
Sources and uses of cash
26.4
25.1
1.0
0.8
23.0 0.2
4.3
1.2
9.9
0.7 16.9 5.2
Divestments
0.7
4.9
Cash Flow from 21.8
operations
14.6
15.5
Others
10.6
2007 2008
Capex Dividends
Buy Back Acquisitions
12
13. Net Financial Debt
Billion €
Total Debt 20.9
18.4
▪ Short-term 6.8
16.3 - o/w Euro Commercial Paper 3.7
▪ Long-term 14.1
Liquidity & Others (2.5)
Net Debt 18.4
0.38 0.38
Undrawn committed bank lines 5.2
▪ Short-term 3.3
▪ Long-term 1.9
Undrawn uncommitted bank lines 7.1
December December
Strong cash generation
2007 2008
High credit standing
Net debt to equity
Diversified credit lines availability without
MAC and financial covenants
13
14. 2008 Cash Returned to Shareholders
2008 Cash out
May 19th*
2007 Final dividend 2.6 € billion
0.70 € /share
September 22nd*
2008 Interim dividend 2.3 € billion
0.65 € /share
Share buyback YTD 0.8 € billion
=
5.7 € billion
2008 overall cash distribution
* Ex dividend date
14
16. Our Short Term Market Outlook: a Tough Time ahead
Low and Volatile Oil Price
Brent $/bl
150
100
50
0
2005 2006 2007 2008 2009
Weak Gas Market Declining Refining Margins
European demand - Bln cm TRC Brent
$/bl €/bl
600
9 9
8 8
Rest of
400 7 7
Europe 6 6
5 5
200 4 4
3 3
2 2
Italy
0 1 1
2008 2009 2010 2011 2012 2005 2006 2007 2008 2009
16
17. Eni: Ideally Positioned to Cope with Industry Challenges
E&P
Low-cost portfolio
Leading lifting
costs of 7.5 $/bl
Top producer
Leading Player
G&P R&M
Resilient cash generation Limited capital employed
Other
97.0
72.5
65.1
4%
54.4
38.2
28.8 E&P
25.0
E&C 48%
8%
4.1
3.9
3.7 3.5 3.5
3.4 3.4
R&M
10%
2002 2003 2004 2005 2006 2007 2008
G&P
30%
EBIT adj. bln € Brent $/bl
17
18. E&P: Sustainable Organic Growth
E&P
kboe/d
+3.5%
>2,050
>1,850
1,797
Large player in fastest
growing areas
2008 2009 2012
Strong presence in giant
97 $/bl 43 $/bl 55 $/bl projects
Focus on three core regions
85% of new
production
Top producer
breakeven <45$/bl*
Leading Player
Reserve replacement ratio
130 in 2009-2012
18
* @ WACC adjusted for country risk
19. G&P: Resilient Cash Generation
Strengthen our 21% leading market share in Europe
Enhance flexibility leveraging on Distrigas acquisition
Preserve the leading position in the Italian gas market
Sales outside Italy: +7% CAGR 2008-12
Cumulative 2009-12 Ebitda pro-forma: € 20 bln
19
20. R&M: Improve Profitability
Selective upgrade in refining with focused capex
Market share growth in Italy
Enhanced operational efficiency
2012 +400 mln € Ebit vs 2008
Cash neutral by 2010
20
21. Efficiency Programme to Enhance Profitability
Corporate E&P
Opex $/bl
5.9
+100% 5.5
Eni
+1.4% -7.1%
Direct costs 5.0
savings
(real term cagr) Benchmark
2005-08 2008-12 Group* 2007 2008 2012
Bln €
Procurement & ICT processes and Technology improvements &
structure streamlining operational excellence
~2.0
Overheads reduction Procurement optimization
~1.0
~1.0
G&P R&M
~1.0
-9.7% -6.6%
CAGR
90%
0.7
0.6
achieved
22.8
Cost savings
16.8
Mass market by 2008
12.8 ($/bl of refining
costs to serve
capacity)
(€/customer)
New
2006-2010 2006-2012
2005-08 2008-12
2005 2008 2012 initiatives
CRM optimization Overheads reduction
Real term, base line 2005
Overheads reduction Energy savings
* ExxonMobil, BP, Shell, Chevron, ConocoPhillips, Total (based on company reports); Eni included
21
22. Disciplined Capex to Fuel Growth
Bln €
49.8 (1.0) 48.8
Others 1.0
1.0 High resilience in low oil
Saipem 4.7 3.9
price scenario
2.8
R&M 4.1
7.0
High flexibility: E&P
G&P 6.5
capex ~25% uncommitted
Stogit 1.8 1.5
in 2009-10; ~85%
uncommitted in 2011-12
E&P 31.7 32.6
Spending optimisation
2009 capex:
€14.1 bln
2008-2011 Variation 2009-2012
Capex plan Capex plan
Attractive capex programme
22
23. Cash Allocation Priorities
Commitment to maintain strong credit rating
Attractive and flexible capex program
Superior dividend yield
23
25. Record Production
2008 Production Growth (%)
Production @
kboe/d
64 $/boe: 1,846
+5.6% kboe/d, well
net of PSA above target
3.5
Eni
+2.1% +3.5%
1,854
2000
1,815 1.797
1.736
0.5
BP
1800
1600
-2.0
Shell
1400
1200
1000
-2.1
Total
800
600
Chevron -3.4
400
200
ConocoPhillips -3.9
0
2008
4Q 07 4Q 08 2007 reported
-6.2
ExxonMobil
Brent 88.7 54.9 72.5 97
($/bl)
Reported PSA effect 1$/bl: ~ 1.5 kboe/d
25
26. Selective M&A
Eni’s M&A vs Peers
2008 M&A
70-80 $/bl
Burren
First Calgary
Other
competitors
11 billion USD in
2007-2008
Other
competitors
>100 kboed in 2008
10 $/MMBTU
250 kboed at 2012 8 $/MMBTU
Other
competitors
NPV value + 18% vs
consideration
Break even price
3P reserves + 10 %
Eni breakeven <50 $/bl; <6 $/MMBTU
26
27. Solid Reserve and Resource base
Proved Reserves Total Resources
(Bln boe) (Bln boe)
RRR Organic : 130% Solid resource base to
RRR
sustain long term growth ~29
RRR All sources : 135% ~ 83% @96$
(0.7)
0.9
~13.5
6.6
6.4
95%
~6.6
sustainable
@30$/bl
Proved Proved+Probable Total*
2007 Promotions Production 2008
Life index Life index
10.0 10.0 10.0 20.5 44
(year) (year)
Year-end Brent
96 36.5 Long term price 57 $/bl (real)
Brent ($/bl)
($/bl) *Proved + Unproved Reserves + Contingent Resources + Risked exploration
From consolidated subsidiaries and share of equity affiliates and unconsolidated entities
27
Eni’s 30% equity in Russian assets, 20% GazPromNeft not included
28. Exploration Success
NORWAY
Aphrodite UK
Gamma
Marulk Culzean
LIBYA CROATIA
Ika
US GoM U1 NC 41 PAKISTAN
D1 NC41
Stones Saquib 1A
Kodiak Latif
Hadrian B
ITALY
Aransas Deep
Cassiopea-1
Argo-2
2008 main discoveries EGYPT
New unconventional projects NIGERIA Ha’py 9
Key areas Bonga N
CONGO
VENEZUELA
ANGOLA AUSTRALIA
Sangos Kitan
N’Goma
Rate of Success >70% with effective time to market
Strategic positioning in growing plays
89% of new acreage in 5 years, nearly all operated
4.3 bln boe from exploration since 2004 (1.1 bln boe in 2008)
28
29. Eni Growth Story and Future Goals
Production since 1998
kboe/d
Focus on CAGR
~ 3.0 %
sustainable 3.5%
>2,050
projects in main
2000 1,797
core regions
5.6%
1500
Increasing
1,038
exposure to Giants 1000
Eni’s unique 500
approach in co-
operation with 0
producing countries 1998 2008 2009 2012 2015
Brent 13 97 43 55 59
($/bl)
Superior growth and resilience under current conditions
29
30. Focus on Core Regions
5.6
Top IOC producer
9.0 (1° or 2°)
Leading player
Average lifting costs
7.4
7.5 $/bl
Production 2008 Production 2012
1,797 kboe/d >2,050 kboe/d
FSU 7% FSU 9%
Others 8% Others 8%
Africa 54%
Africa 55%
OECD 28%
OECD 31%
30
32. Resilient Portfolio: Highly Profitable Growth
Breakeven* of New Production
2009-2012
70
60
50
Breakeven ($/bl)
40
30
20
10
0
100 200 300 400 525
New production (kboe/d)
32
* At WACC adjusted for country risk
33. Growing Exposure to Giant Projects
Giant Projects Equity Production
kboe/d
Operated
69% 73% 79%
production
~1,080
~930
859
Start-ups & growth
Producing
2008 2012 2014
Present in 37 giant projects (>0.5 bln boe), of which 18 operated
33
Source: Goldman Sachs “top 190 projects” and Eni elaboration
34. Capex 2009-12
Capex 2009-12 2009 Capex Budget
bln euro
Total
2.8%
9.2 bln euro
32.6
31.7 -5.0
5.9
-19%
1.8
2.1
4.1 -13%
4.7
Exploration Development Others
Portfolio Flexibility
26.9 +7%
24.9
Committed Uncommitted
100%
80%
60%
Additional Spending
2008-11 2009-12
40%
activities/ optimization
Rephasing/
20%
Inflation
0%
Development Others
Exploration 2009 2010 2011 2012
Spending optimisation and growth resilience
2008-11 Excluding non consolidated capex (3.3 bln €), Burren cash out (2 bln €), Storage (1.8 bln €) and exchange rate effect
34
2009-12 Excluding non consolidated investment (1.5 bln €)
35. Resilient operations
Average lifting costs 7.5 $/bl
Current production
85% of new production sustainable @ 45 $/bl
New Projects
95% of 2P reserves robust @ 30$
Reserves
35
37. 2008 Results
EBITDA pro forma adjusted
Mln €
Q4 08/Q4 07 5,077 (62)
highlights
4,466
720 (549)
755 +4.9%
Lower volumes sold, 1,289
particularly in Italy 1,401 +8.7%
Reduced electricity
sales 3,068
2,310 -24.7%
US$ appreciation
2007 9M 08 Q4 08 2008
International Regulated businesses Marketing
Transportation in Italy
37
38. Weaker Outlook for Gas Demand in Europe
Tough competitive environment in Italy:
1% decline in gas consumption expected in 2009
2% CAGR in the plan period
Additional import capacity
Revised European gas demand:
Flat in 2009
2% CAGR in the following years
Direct entry of gas producers into the end-user market
Cautious near-term prospects, normalizing in the medium term
38
39. Italy: Preserving Profitability
Focus on higher-margin and most loyal customers:
Gas fired power generation segment: maintain market share
Industrial segment: cherry-pick clients
Residential segment: extend dual offer and overall customer base
Further efficiency gains
Maintain the leading position in the Italian gas market
39
40. International Sales
Bcm
Benelux
UK/NW
Europe 22%
Germany/
Strong growth in the core 14.8
Austria
13.5*
6.8
European markets 7%
7.6
3.2
5.3
despite increasing 2.4
2.2
2008 2012
competition and slowing 5.2
2008 2012
3.1
2008 2012
demand
Extra-European sales at Turkey
France
6.9 Bcm in 2012 14%
13%
6.4
6.8
Iberian 4.9
4.0*
Peninsula
16%
8.6
Sales outside Italy: 7.5 2008 2012
2008 2012
7% CAGR 2008-2012** 5.8
4.1
Market share in 2012
3.1
3.3
Consolidated
2008 2012
Associates
Strengthen European leadership in a weak market environment
* 100% Distrigas sales
40
** Includes 100% Distrigas in 2008 and excludes sales to importers in Italy
41. 2009-12 Targets
Gas Sales (Bcm) Cumulated EBITDA (Bln €)
124 20
19
114
15%
16%
Steady expansion 61% 30%
31%
49%
in international
sales despite 104
55%
weak demand 53%
39%
51%
Resilient results
in all business
Pro-forma 2012 2008-11 2009-12
segments 2008
Previous New
target target
Abroad* Italy Int. Transport Regulated
businesses in
Italy
Distrigas sales @ 100% Marketing
* Including E&P gas sold in Europe and Gulf of Mexico
41
42. 2009-12 Capex Plan
Bln €
7.0
€5.3 billion in regulated
6.5
business with guaranteed
25%
13%
return
€0.7 billion in international
storage to increase flexibility
87% 75%
€0.7 billion in power
generation to consolidate
Italian market share
2008-11 Plan 2009-12 Plan
Regulated Marketing
businesses and Power
42
44. 2008 Results
EBIT Adjusted
Mln €
566
41
196
329
FY 2007 Scenario Performance FY 2008
+60% +12% +72%
Favorable refining scenario in 2H08
Higher retail contribution margin: +24%
Italian retail market share: +140bp to 30.6%
Cost savings: 6% workforce reduction in Italy
44
45. Refining & Marketing Vision
Declining Demand Operational Efficiency
Declining
Enhance
Refining
Profitability
Scenario
New capacity Widespread Rationalization Focused
in Middle and upgrading of refining growth in
Far East capacity and marketing
selective
capex
45
46. Profitability Enhancement
Refining Marketing
Start up of 3 hydrocrackers in Increase retail market share in Italy
2009
Reach critical mass (>10%) in
EST plant start up by 2012 Central-Eastern Europe
Improve conversion index and Strengthen non oil activities,
Market share
operational flexibility customers loyalty and service
> 30%
> 10% quality
4-8%
45%
Middle 40%
57
distillate yield
65
32%
31%
Market
65% Main upgrading investments
57%
Conversion share in Italy
2008 2012
index
-4%
2008 2012
Employees 2008 vs 2012
Cost efficiency up to € 150 mln by 2012
2012 + €400 mln Ebit vs 2008
Free cash flow positive by 2010
46
47. Reduced Capex Plan
Bln €
-30%
4.0
Other
2.8
Refining
22%
70%
45%
EST
75% Sannazzaro
33%
Marketing
30%
25%
Plan Plan
08-11 09-12
Stay in Development
Business
47
48. Growth and Value
Cash neutrality
Strong and resilient cash generation @ 41$/bl in
2012
Sustainable and efficient growth across core activities
Superior returns to shareholders
48
49. Disclaimer
Data and information herewith set forth are extracted from Eni’s press release on the fourth quarter of 2008 filed with Italian
authorities regulating exchanges and securities and disseminated concomitantly with this presentation. The press release
on the fourth quarter of 2008 includes the certification rendered by the company CFO, in his quality as manager
responsible for the preparation of financial reports, pursuant to article 154-bis paragraph 2 of legislative decree No.
58/1998 stating that the quarterly accounts correspond to the company’s evidence and accounting books and entries.
This presentation contains forward-looking statements regarding future events and the future results of Eni that are based
on current expectations, estimates, forecasts, and projections about the industries in which Eni operates and the beliefs
and assumptions of the management of Eni. In particular, among other statements, certain statements with regard to
management objectives, trends in results of operations, margins, costs, return on equity, risk management and competition
are forward-looking in nature. Words such as ‘expects’, ‘anticipates’, ‘targets’, ‘goals’, ‘projects’, ‘intends’, ‘plans’,
‘believes’, ‘seeks’, ‘estimates’, variations of such words, and similar expressions are intended to identify such forward-
looking statements. These forward-looking statements are only predictions and are subject to risks, uncertainties, and
assumptions that are difficult to predict because they relate to events and depend on circumstances that will occur in the
future. Therefore, Eni’s actual results may differ materially and adversely from those expressed or implied in any forward-
looking statements. Factors that might cause or contribute to such differences include, but are not limited to, economic
conditions globally, the impact of competition, political and economic developments in the countries in which Eni operates,
regulatory developments in Italy and internationally and changes in oil prices and in the margins for Eni products. Any
forward-looking statements made by or on behalf of Eni speak only as of the date they are made. Eni does not undertake
to update forward-looking statements to reflect any changes in Eni’s expectations with regard thereto or any changes in
events, conditions or circumstances on which any such statement is based. The reader should, however, consult any
further disclosures Eni may make in documents it files with the US Securities and Exchange Commission.
49
58. Main Operating Data
Q4 08 2007 2008 Δ%
Q4 07
1,815 1,854 Hydrocarbon prod. (kboe/d) 1,736 1,797 3.5
162.1 163.2 Production sold* (mmboe) 611.4 632 3.4
16.2 13.3 Natural gas sales in Italy**(bcm) 56.1 52.8 (5.8)
8.8 13.8 Natural gas sales in Europe*** (bcm) 27.9 35.6 27.8
9.3 9.11 Natural gas transported on behalf 30.9 33.8 9.6
of third parties in Italy (bcm)
8.3 6.9 Power production sold (TWh) 33.2 29.9 (9.8)
13.9 12.1 Refined product sales (mmtonnes) 50.2 50.7 1.1
1.3 0.9 Petrochemical sales (mmtonnes) 5.5 4.7 (14.5)
* Including Eni’s share of production of joint venture accounted for with the equity method
** Including self-consumption 58
*** Consolidated sales
59. Production by Geographical Area
Kboe/d
+2.1% +3.5%
1,854
1,815 1,797
1,736
301
261 258
230
111 128 123 Rest of World
112
279 244 237 Caspian Area
261
North Sea
316 356 335
327 West Africa
North Africa
Italy
641 645
635 594
207 212
190 199
Q4 2007 Q4 2008 FY 2007 FY 2008
59