<SEC-DOCUMENT>0001311435-11-000014.txt : 20130124
<SEC-HEADER>0001311435-11-000014.hdr.sgml : 20130124
<ACCEPTANCE-DATETIME>20110920133737
<PRIVATE-TO-PUBLIC>
ACCESSION NUMBER:		0001311435-11-000014
CONFORMED SUBMISSION TYPE:	CORRESP
PUBLIC DOCUMENT COUNT:		2
FILED AS OF DATE:		20110920

FILER:

	COMPANY DATA:	
		COMPANY CONFORMED NAME:			ENI SPA
		CENTRAL INDEX KEY:			0001002242
		STANDARD INDUSTRIAL CLASSIFICATION:	CRUDE PETROLEUM & NATURAL GAS [1311]
		IRS NUMBER:				000000000
		FISCAL YEAR END:			1231

	FILING VALUES:
		FORM TYPE:		CORRESP

	BUSINESS ADDRESS:	
		STREET 1:		PIAZZALE ENRICO MATTEI 1
		CITY:			ROME ITALY
		STATE:			L6
		ZIP:			00144
		BUSINESS PHONE:		011390659824367

	MAIL ADDRESS:	
		STREET 1:		PIAZZALE ENRICO MATTEI 1
		CITY:			ROME ITALY
		STATE:			L6
		ZIP:			00144
</SEC-HEADER>
<DOCUMENT>
<TYPE>CORRESP
<SEQUENCE>1
<FILENAME>filename1.htm
<TEXT>
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<head>
<title>sj200911correspenil</title>
</head>

<body bgcolor="#FFFFFF">

<table border="0" cellpadding="0" cellspacing="0" width="100%">
    <tr>
        <td align="right" valign="top" colspan="2"><p
        align="right"><font size="1" face="Arial"><b><i>Eni
        S.p.A. has claimed confidential treatment of portions <br>
        of this letter in accordance with 17 C.F.R. &#167; 200.83</i></b></font></p>
        </td>
    </tr>
    <tr>
        <td valign="bottom" rowspan="2" width="80%"><img
        src="sjlogonewcol.gif" width="78" height="95"></td>
        <td valign="bottom" rowspan="2" width="20%"><font
        size="1">Sede legale in Roma<br>
        Piazzale Enrico Mattei, 1 <br>
        00144 Roma<br>
        Tel. centralino: +39 06598.21<br>
        www.eni.com</font></td>
    </tr>
</table>

<p align="right">&nbsp;</p>

<table border="0" cellpadding="0" cellspacing="0" width="100%">
    <tr>
        <td valign="top" width="60%"><p align="left"><b>ALESSANDRO
        BERNINI</b></p>
        </td>
        <td valign="top" width="40%">&nbsp;</td>
    </tr>
    <tr>
        <td valign="top" width="60%"><p align="left">CHIEF
        FINANCIAL OFFICER</p>
        </td>
        <td valign="top" width="40%">&nbsp;</td>
    </tr>
    <tr>
        <td valign="top" width="60%">Direct Telephone
        (+39)-02-52041730</td>
        <td valign="top" width="40%">&nbsp;</td>
    </tr>
    <tr>
        <td valign="top">Fax (+39)-02-52041765</td>
        <td valign="top">&nbsp;</td>
    </tr>
    <tr>
        <td valign="bottom" width="60%"><font size="2">&nbsp;&nbsp;&nbsp;</font><br>
        Prot. CFO/63/2011</td>
        <td valign="bottom" width="40%">September 20, 2011</td>
    </tr>
</table>

<table border="0" cellpadding="0" cellspacing="0" width="100%">
    <tr>
        <td valign="bottom" width="40%"><font size="2">&nbsp;</font><br>
        </td>
        <td valign="bottom" width="60%"><font size="2">&nbsp;</font><br>
        United States Securities and Exchange Commission</td>
    </tr>
    <tr>
        <td valign="bottom" width="40%">&nbsp;</td>
        <td valign="bottom" width="60%">100 F Street N.E., Stop
        7010</td>
    </tr>
    <tr>
        <td valign="bottom" width="40%">&nbsp;</td>
        <td valign="bottom" width="60%">Washington, D.C. 20549</td>
    </tr>
</table>

<table border="0" cellpadding="0" cellspacing="0" width="100%">
    <tr>
        <td valign="bottom" width="70%">&nbsp;</td>
        <td valign="bottom" width="30%">Attention: Mr. H. Roger
        Schwall</td>
    </tr>
    <tr>
        <td valign="bottom" width="70%">&nbsp;</td>
        <td valign="bottom" width="30%">Assistant Director</td>
    </tr>
    <tr>
        <td valign="bottom" width="70%">&nbsp;</td>
        <td valign="bottom" width="30%">Division of Corporation
        Finance</td>
    </tr>
    <tr>
        <td valign="bottom" width="70%">&nbsp;</td>
        <td valign="bottom" width="30%">&nbsp;</td>
    </tr>
    <tr>
        <td valign="bottom" width="70%"><b>Re: Eni S.p.A.</b></td>
        <td valign="bottom" width="30%">&nbsp;</td>
    </tr>
    <tr>
        <td valign="bottom" width="70%"><b>Form 20-F for Fiscal
        Year Ended December 31, 2010</b></td>
        <td valign="bottom" width="30%">&nbsp;</td>
    </tr>
    <tr>
        <td valign="bottom" width="70%"><b>Filed April 7, 2011</b></td>
        <td valign="bottom" width="30%">&nbsp;</td>
    </tr>
    <tr>
        <td valign="bottom" width="70%"><b>Form 20-F/A for Fiscal
        Year Ended December 31, 2009</b></td>
        <td valign="bottom" width="30%">&nbsp;</td>
    </tr>
    <tr>
        <td valign="bottom" width="70%"><b>Filed April 7, 2011</b></td>
        <td valign="bottom" width="30%">&nbsp;</td>
    </tr>
    <tr>
        <td valign="bottom" width="70%"><b>File No. 1-14090</b></td>
        <td valign="bottom" width="30%">&nbsp;</td>
    </tr>
</table>

<p>&nbsp;</p>

<p>Dear Mr. Schwall:</p>

<p>Thank you for your letter dated August 19, 2011 setting forth
comments of the Staff of the Commission relating to Eni&#146;s
annual report on Form 20-F for the year ended December 31, 2010
(the &quot;2010 Form 20-F&quot;) and Form 20-F/A for the year
ended December 31, 2009. The information set forth below is
submitted in response to your comments. The numbered paragraphs
and headings correspond to the numbered paragraphs and headings
of your letter.</p>

<p align="center">&nbsp;</p>

<table border="0" cellpadding="0" cellspacing="0" width="100%">
    <tr>
        <td rowspan="2" width="65%">&nbsp;</td>
        <td rowspan="2" width="35%"><font size="1">Capitale
        sociale Euro 4.005.358.876,00 i.v.<br>
        Registro Imprese di Roma, Codice fiscale 00484960588<br>
        Partita IVA 00905811006, R.E.A. Roma n. 756453<br>
        Sedi secondarie:<br>
        Via Emilia, 1 - Piazza Ezio Vanoni, 1<br>
        20097 San Donato Milanese (MI)</font></td>
    </tr>
</table>

<p align="center">- 1 -</p>

<hr noshade>

<p style="page-break-before:always"><font size="2">&nbsp;&nbsp;</font></p>

<table border="0" cellpadding="0" cellspacing="0" width="100%">
    <tr>
        <td align="right" valign="top" colspan="2"><p
        align="right"><font size="1" face="Arial"><b><i>Eni
        S.p.A. has claimed confidential treatment of portions <br>
        of this letter in accordance with 17 C.F.R. &#167; 200.83</i></b></font></p>
        </td>
    </tr>
</table>

<p>&nbsp;</p>

<p>In accordance with the Staff&#146;s policy with respect to
requests for confidential treatment of responses to the
Staff&#146;s comment letters, we are submitting two separate
letters to the Staff&#146;s comments. Concurrent with the
submission to you of this letter, confidential treatment of
portions of this letter is being requested under the
Commission&#146;s rules in accordance with 17 C.F.R. &#167; 200.83.
Accordingly, a separate version of this response letter
containing confidential information of the Company is being filed
by hand and not via EDGAR. This letter being submitted via EDGAR
does not contain confidential information of the Company and,
therefore, is not submitted on a confidential basis.</p>

<p><b><u>Form 20-F for the Fiscal Year Ended December 31, 2010</u></b></p>

<p>&nbsp;</p>

<p><b><u>Petroleum Engineering Comments </u></b></p>

<p><b><u>Risk Factors, page 5 </u></b></p>

<p><b><u>Risks associated with the exploration and production of
oil and natural gas, page 6</u></b></p>

<blockquote>
    <p><strong>1. Please expand your disclosure here to present
    the consequences of loss of hydrocarbon containment during
    drilling, transportation and processing. Address offshore
    operations separately.</strong></p>
</blockquote>

<p>In response to the Staff comment, in our future filings we
plan to expand our risk-factor disclosure as follows (changes are
highlighted in bold):</p>

<p>&quot;Risks associated with the exploration and production of
oil and natural gas <b>and other Group&#146;s operations</b></p>

<p>The exploration and production of oil and natural gas requires
high levels of capital expenditures and entails particular
economic risks. It is subject to natural hazards and other
uncertainties including those relating to the physical
characteristics of oil and natural gas fields. <b>In addition,
the Group engages in processing, transportation, refining and
petrochemical activities, storage and distribution of petroleum
products, natural gas transportation, distribution and storage,
and production of base chemical and specialty products, which
involve a wide range of operational risks. <br>
</b>Eni&#146;s results depend on its ability to identify and
mitigate the risks and hazards inherent to operating in <b>those
industries</b>. The Company seeks <b>to minimize these
operational risks by carefully designing and building its
facilities, including wells, industrial complexes, plants and
equipment, pipelines, storage sites and distribution networks, </b>and
conducting its operations in a safe </p>

<p align="center">- 2 -</p>

<hr noshade>

<p style="page-break-before:always"><font size="2">&nbsp;&nbsp;</font></p>

<table border="0" cellpadding="0" cellspacing="0" width="100%">
    <tr>
        <td align="right" valign="top" colspan="2"><p
        align="right"><font size="1" face="Arial"><b><i>Eni
        S.p.A. has claimed confidential treatment of portions <br>
        of this letter in accordance with 17 C.F.R. &#167; 200.83</i></b></font></p>
        </td>
    </tr>
</table>

<p>&nbsp;</p>

<p>and reliable manner. However, failure to manage these risks
effectively could result in unexpected incidents, including
releases, explosions or mechanical failures resulting in personal
injury, loss of life, environmental damage, loss of revenues, <b>and
increase in cost,</b> legal liability and/or <b>damage or
destruction of crude oil or natural gas wells as well as
equipment and other property, all of which could lead to a </b>disruption
in operations<b>. We also face risks once production is
discontinued, because our activities require environmental site
remediation.<br>
</b>In exploration and production, <b>we encounter risks related
to the physical characteristics of our oil or gas fields. These
include the risks of eruptions of crude oil or of natural gas,
discovery of hydrocarbon pockets with abnormal pressure,
crumbling of well openings, leaks that can harm the environment
and risks of fire or explosion.<br>
</b>Accidents at a single well can lead to loss of life, <b>damage
or destruction to property</b>, environmental damage and
consequently potential economic losses that could have a material
and adverse effect on the business, results of operation and
prospects of the Group. </p>

<p><b>Eni&#146;s activities in the Refining &amp; Marketing and
Petrochemicals sectors also entail additional health, safety and
environmental risks related to the overall life cycle of the
products manufactured, as well as raw materials used in the
manufacturing process, such as catalysts, additives and monomer
feedstock. These risks can arise from the intrinsic
characteristics of the products involved (flammability, toxicity,
or long-term environmental impacts such as greenhouse gas
emissions), their use, emissions and discharges resulting from
their manufacturing process, and from recycling or disposing of
materials and wastes at the end of their useful life.</b></p>

<p><b>In the transportation area, the type of risk depends not
only on the hazardous nature of the products transported, but
also on the transportation methods used (mainly pipelines,
maritime, river-maritime, rail, road, gas distribution networks),
the volumes involved, and the sensitivity of the regions through
which the transport passes (quality of infrastructure, population
density, environmental considerations). All modes of
transportation of hydrocarbons are particularly susceptible to a
loss of containment of hydrocarbons and other hazardous
materials, and, given the high volumes involved, could present a
significant risk to people and the environment. </b></p>

<p align="center">- 3 -</p>

<hr noshade>

<p style="page-break-before:always"><font size="2">&nbsp;&nbsp;</font></p>

<table border="0" cellpadding="0" cellspacing="0" width="100%">
    <tr>
        <td align="right" valign="top" colspan="2"><p
        align="right"><font size="1" face="Arial"><b><i>Eni
        S.p.A. has claimed confidential treatment of portions <br>
        of this letter in accordance with 17 C.F.R. &#167; 200.83</i></b></font></p>
        </td>
    </tr>
</table>

<p>&nbsp;</p>

<p>Eni has implemented and maintains a system of policies,
procedures and compliance mechanisms to manage safety, health,
environmental, reliability and efficiency risks; to verify
compliance with applicable laws and policies; and to respond to
and learn from unexpected incidents. Nonetheless, in certain
situations where Eni is not the operator, the Company may have
limited influence and control over third parties, which may limit
its ability to manage and control such risks. Eni maintains
insurance coverage that include coverage for physical damage to
our assets, third party liability, workers&#146; compensation,
pollution and other damage to the environment and other coverage.
Our insurance is subject to caps, exclusion and limitation, and
there is no assurance that such coverage will adequately protect
us against liabilities from all potential consequences and
damages. In light of the accident at the Macondo well in the Gulf
of Mexico, we may not be able to secure similar coverage for the
same costs. Future insurance coverage for our industry could
increase in cost and may include higher retentions. Also, some
forms of insurance may become unavailable in the future or
unavailable on terms that we believe are economically acceptable.</p>

<p>The production of oil and natural gas is highly regulated and
is subject to conditions imposed by governments throughout the
world in matters such as the award of exploration and production
interests, the imposition of specific drilling and other work
obligations, income taxes and taxes on production, environmental
protection measures, control over the development and abandonment
of fields and installations, and restrictions on production.</p>

<p><b>Our oil and natural gas operations are particularly exposed
to health, safety, security and environmental risks.</b></p>

<p><b>We have material operations relating to the exploration and
production of hydrocarbons located offshore. In 2010
approximately 60% of our total oil and gas production for the
year derived from offshore fields, mainly in Egypt, Libya,
Norway, Angola, Italy, Gulf of Mexico and UK. Offshore operations
in the oil and gas industry are inherently riskier than onshore
activities. As recent events in the Gulf of Mexico have shown,
the potential impacts of offshore accidents and spills to health,
safety, security and the environment can be catastrophic due to
the objective difficulties in handling hydrocarbons containment
and other factors. Also offshore operations are subject to marine
perils, including severe storms and other adverse weather
conditions and vessel collisions, as well as interruptions or
termination by governmental authorities based on safety,
environmental and other considerations. Failure to manage these
risks could result in </b></p>

<p align="center">- 4 -</p>

<hr noshade>

<p style="page-break-before:always"><font size="2">&nbsp;&nbsp;</font></p>

<table border="0" cellpadding="0" cellspacing="0" width="100%">
    <tr>
        <td align="right" valign="top" colspan="2"><p
        align="right"><font size="1" face="Arial"><b><i>Eni
        S.p.A. has claimed confidential treatment of portions <br>
        of this letter in accordance with 17 C.F.R. &#167; 200.83</i></b></font></p>
        </td>
    </tr>
</table>

<p>&nbsp;</p>

<p><b>injury or loss of life, damage to property, environmental
damage, and could result in regulatory action, legal liability,
loss of revenues and damage to our reputation and could have a
material adverse effect on our operations or financial
condition.&quot;</b></p>

<p>In addition, please note that our 2010 Form 20-F included
separate risk disclosure relating to the regulatory risk and
associated costs relating in particular to deep water drilling
following the Macondo accident, which we plan to repeat or update
as appropriate in future filings. See &quot;The oil and gas
industry may face increased regulation both in the USA and
elsewhere that could increase the cost of regulatory compliance
and may require changes to our drilling operations and
exploration and development plans and may lead to higher
royalties and taxes&quot; on page 7 of the 2010 20-F.</p>

<p><b><u>Information on Company, page 22 <br>
Significant Business and Portfolio Developments, page 24 </u></b></p>

<p>&nbsp;</p>

<p><b>2. We note the reference to the Zubair field here and page
50. Please: </b></p>

<ul>
    <li><b>Tell us the figures for Zubair proved reserves and
        proved undeveloped reserves that you have booked;</b></li>
    <li><b>Illustrate the computation of your projected annual
        production entitlement and proved reserves for year-end
        2010 as governed by the technical service contract; </b></li>
    <li><b>Explain your claim to reserves in light of the
        provisions of your technical service contract, i.e.
        profit oil at $2/barrel; and </b></li>
</ul>

<p><b>Address whether you have the option for payment in kind for
cost recovery and profit payment. </b></p>

<p>Eni&#146;s proved reserves booked at the end of 2010 for the
Zubair field represented less than [***] of our total proved
reserves, with the vast majority of that amount classified proved
undeveloped. </p>

<p>In our letters dated October 29, 2010 and February 11, 2011 in
response to the Staff comments on our 2009 Form 20-F, we briefly
illustrated the contractual terms and the basis for our claim to
proved reserves as of the end of 2009.<br>
Under the Zubair Technical Service Contract, Eni and its partners
are required to increase the field&#146;s production from an
initial level of approximately 0.2 million barrel of oil per day
to 1.2 million over a period of six years and maintain such level
for a period of seven years thereafter.</p>

<table border="1" cellpadding="6" cellspacing="0" width="100%"
bordercolor="#000000">
    <tr>
        <td width="100%"><font size="1" face="Verdana">[THE
        SYMBOL &quot;***&quot; ON THIS PAGE REPRESENTS THAT
        CONFIDENTIAL TREATMENT HAS BEEN OMITTED AND FURNISHED
        SEPARATELY TO THE COMMISSION] </font></td>
    </tr>
</table>

<p align="center">- 5 -</p>

<hr noshade>

<p style="page-break-before:always"><font size="2">&nbsp;&nbsp;</font></p>

<table border="0" cellpadding="0" cellspacing="0" width="100%">
    <tr>
        <td align="right" valign="top" colspan="2"><p
        align="right"><font size="1" face="Arial"><b><i>Eni
        S.p.A. has claimed confidential treatment of portions <br>
        of this letter in accordance with 17 C.F.R. &#167; 200.83</i></b></font></p>
        </td>
    </tr>
</table>

<p>&nbsp;</p>

<p>Development of the field includes a Rehabilitation Plan, aimed
at improving the initial production level and knowledge of the
reservoir, and a Redevelopment Plan designed to attain the
scheduled targets. </p>

<p>The Contractor is entitled to a Service Fee which includes the
recovery of Petroleum Costs and a Remuneration Fee. Under the
contract, the Contractor has the option to receive payment of the
Service Fee either in kind or in cash. Eni has elected the former
option. Accordingly, the Service Fee is payable in oil.</p>

<p>The above described contractual terms establish an oil
entitlement mechanism and associated risk profile similar to
those applicable in Production Sharing Contracts since the
Contractor can only earn service fees to the extent incremental
production reaches certain levels. In addition the contract does
not establish a fixed level of oil price for the purpose of
calculating production entitlements. Accordingly, higher oil
prices will reduce Eni's cost oil and profit oil entitlement, and
lower oil prices will increase such entitlement.</p>

<p>The Rehabilitation Plan was approved in June 2010. In the
fourth quarter of 2010 actual production from the field exceeded
the contractual baseline by more than 10% triggering Eni&#146;s
contractual right to book its equity production in relation to
its share of cost recovery and remuneration.</p>

<p>Proved reserve entitlements have been calculated as follows.
First, Eni calculated projected production at the field based on
available technical data. Second, the amount of Service Fee was
calculated based on costs and projected production. Third, the
dollar amount of Service Fee calculated as above was divided by
the relevant market price determined in accordance with
applicable SEC regulation. </p>

<p>&nbsp;</p>

<p><b>3. Tell us whether you claim proved reserves under service
contracts elsewhere (e.g. the Villano field on page 25). If so,
please tell us the proved figures for each field and the
justification for your claims to proved reserves.</b></p>

<p>Proved reserves related to properties regulated under service
contracts other than Zubair mainly relate to Villano field in
Ecuador, Agbara and Okono-Okpoho fields in Nigeria and Iranian
fields, which cumulatively represented less than [***] of our
total proved reserves as of end of 2010. <br>
The various service contracts applicable to those fields differ
in several aspects, but in all cases the risk profile, as well as
the entitlement to oil production, is similar to that applicable
in Production Sharing Contracts, because the costs incurred by
Eni </p>

<table border="1" cellpadding="6" cellspacing="0" width="100%"
bordercolor="#000000">
    <tr>
        <td width="100%"><font size="1" face="Verdana">[THE
        SYMBOL &quot;***&quot; ON THIS PAGE REPRESENTS THAT
        CONFIDENTIAL TREATMENT HAS BEEN OMITTED AND FURNISHED
        SEPARATELY TO THE COMMISSION] </font></td>
    </tr>
</table>

<p align="center">- 6 -</p>

<hr noshade>

<p style="page-break-before:always"><font size="2">&nbsp;&nbsp;</font></p>

<table border="0" cellpadding="0" cellspacing="0" width="100%">
    <tr>
        <td align="right" valign="top" colspan="2"><p
        align="right"><font size="1" face="Arial"><b><i>Eni
        S.p.A. has claimed confidential treatment of portions <br>
        of this letter in accordance with 17 C.F.R. &#167; 200.83</i></b></font></p>
        </td>
    </tr>
</table>

<p>&nbsp;</p>

<p>to develop and operate those fields are reimbursable to the
extent that there exists amounts of marketable hydrocarbons
production. For these reasons Eni deems it appropriate to book
reserves in respect of such contracts.</p>

<p>In relation to the Villano field, under the terms of the
service contract, the contractor is entitled to receive a service
fee based on a capped remuneration tariff per barrel. The level
of cost recovery and profitability therefore is subject to
variation in market prices and field production performance.</p>

<p>The two Nigerian contracts are defined as Service Contracts,
but the contractual terms actually contemplate a mechanism of
cost recovery and profit oil that is the same as in PSAs.</p>

<p>For the description of the Iran Service contract please refer
to our letter dated February 11, 2011 in response to the Staff
comments about our 2009 Form 20-F.</p>

<p>&nbsp;</p>

<p><b><u>Summary of Proved Oil and Gas Reserves, page 29 </u></b></p>

<p><b>4. Item 1201(d) of Regulation S-K defines &quot;geographic
area&quot; as a country, a group of countries within a continent
or a continent. Item 1202(a)(2) requires tabular disclosure of
reserves by each geographic area that contains 15% or more of a
registrant&#146;s proved reserves. Please explain to us why you
do not provide such disclosure for North Africa, which accounts
for 33% of your consolidated subsidiary proved reserves. </b></p>

<p>We acknowledge the Staff&#146;s comment. We engage in
exploration and production of oil and natural gas in Egypt,
Libya, Algeria and Tunisia which we group as a single geographic
area denominated North Africa for reserve disclosure purposes.
Instruction 4 to paragraph (a) (2) of item 1202 states that
&quot;A registrant need not provide disclosure of the reserves in
a country containing 15% of more of the registrant&#146;s proved
reserves if that country&#146;s government prohibits disclosure
of reserves in that country.&quot; We believe that providing a
further break-down of geographic areas within North Africa would
result in a breach of instructions that Eni received from the
state-owned company of one such country prohibiting disclosure of
reserves in that country.</p>

<p align="center">- 7 -</p>

<hr noshade>

<p style="page-break-before:always"><font size="2">&nbsp;&nbsp;</font></p>

<table border="0" cellpadding="0" cellspacing="0" width="100%">
    <tr>
        <td align="right" valign="top" colspan="2"><p
        align="right"><font size="1" face="Arial"><b><i>Eni
        S.p.A. has claimed confidential treatment of portions <br>
        of this letter in accordance with 17 C.F.R. &#167; 200.83</i></b></font></p>
        </td>
    </tr>
</table>

<p>&nbsp;</p>

<p><b>5. Revise your table to include your equity accounted
reserves by geographic area. See Question 154.02 of Compliance
and Disclosure Interpretations (October 26, 2009), available at
http://www.sec.gov/divisions/corpfin/guidance/oilandgas-interp.htm.
</b></p>

<p>Eni proved reserves related to equity-accounted entities
represented approximately 8% of total proved reserves as of the
end of 2010. On page 3 of the 2010 Form 20-F, we disclose that
our share of reserves held by equity-accounted entities mainly
relates to our joint-venture operations conducted in Russia since
2007. In addition, we disclosed in the 2010 20-F that we booked
for the first time certain amounts of oil reserves in connection
to the Junin 5 joint project in Venezuela. Other residual amounts
relate to joint venture operations in Africa, America and Asia. <br>
A large part of our proved reserves booked in connection with
joint operations are undeveloped as our initiatives are
progressing towards production. Accordingly, the results of
operations of our equity-accounted entities are immaterial to the
Group&#146;s results of operations. <br>
In light of the foregoing discussion, we believe that disclosing
the geographic break-down of reserves of our equity-accounted
entities would not provide any further meaningful information to
the investor.</p>

<p>As we expect that our joint operations become more significant
to us in the near future, we plan to disclose geographic area
information about our equity-accounted entities starting with the
2011 Form 20-F.</p>

<p>&nbsp;</p>

<p><b>6. We note your statement, &quot;The current SEC rules
allow the use of reliable technology to justify the reserves
estimate if it produces consistent and repeatable results. We did
not have any material additions of proved reserves due to
application of &quot;reliable technologies&quot;. Please explain
to us the technology you used for the additional 776 MMBOE of
additional proved reserves you booked at year-end 2010. </b></p>

<p>In our statement &quot;<b>We did not have any material
additions of proved reserves due to application of </b><b><u>reliable
technologies</u></b>&quot;, the term &quot;reliable
technologies&quot; referred to reliable technologies other than
those that would have allowed a determination of proved amounts
under former SEC rules. In other words, by that statement we
intended to signify that during the year, no material quantities
were booked under current rules incremental to quantities
allowable under former SEC rules as a result of the expanded
range of technologies that may be used in the estimation.</p>

<p align="center">- 8 -</p>

<hr noshade>

<p style="page-break-before:always"><font size="2">&nbsp;&nbsp;</font></p>

<table border="0" cellpadding="0" cellspacing="0" width="100%">
    <tr>
        <td align="right" valign="top" colspan="2"><p
        align="right"><font size="1" face="Arial"><b><i>Eni
        S.p.A. has claimed confidential treatment of portions <br>
        of this letter in accordance with 17 C.F.R. &#167; 200.83</i></b></font></p>
        </td>
    </tr>
</table>

<p>&nbsp;</p>

<p>The actual methods (or technology) used in the proved reserves
assessment depend on stage of development, quality and
completeness of data, and production history available, and the
methods include volumetric estimates, analogies, reservoir
modelling, decline curve analysis or a combination of such
methods. The data considered for these analyses are obtained with
a combination of reliable technologies that include direct
measurements (i.e. well logs, reservoir core samples, pressure
information, fluid samples, production test data, and performance
data) and indirect measurements (i.e. seismic data). All of the
776 MMBOE of additional proved reserves were booked using
reliable technologies within the meaning of Rule 4-10 of
Regulation S-X currently in force.</p>

<p>Of the total proved reserves additions (776 MMBOE) booked by
Eni at year end 2010, 125 MMBOE refer to discovery and extension.<br>
General revisions, which account for the remaining additions,
mainly related to brown fields&#146; reservoir studies, where
changes are predominantly based on field performances and decline
curve analysis, development activities (infill drilling and
production optimization projects), and the updating of natural
gas conversion factor from 5,742 to 5,550 standard cubic feet of
gas per barrel of oil equivalent.</p>

<p>&nbsp;</p>

<p><b><u>Proved Undeveloped Reserves, page 31 </u></b></p>

<p><b>7. We note your statement, &quot;In 2010, total proved
undeveloped reserves increased by 354 mmBOE. The principal
reasons for the increase are revisions and new projects sanction,
mainly in Libya, Venezuela and Iraq.&quot; Please expand this to
present figures for PUD increases due to revisions and the
figures due to new project sanctions. </b></p>

<p>In 2010, total proved undeveloped reserves increased by 354
MMBOE. Additions relating to new project sanctions amounted to
approximately 280 MMBOE. <br>
The remaining proved undeveloped reserves increase resulted from
upwards and downwards revisions mainly related to contractual and
technical revisions, price effects&nbsp;and the updating of the
natural gas conversion factor from 5,742 to 5,550 standard cubic
feet of gas per barrel of oil equivalent that is disclosed
elsewhere in the 2010 Form 20-F. </p>

<p>&nbsp;</p>

<p><b>8. We note that you have claimed PUD reserves at Kashagan
for more than five years. Please tell us if your booked PUD
reserves - .6 BBOE - are to be developed entirely in Phase 1. If
not, please justify your claim to proved reserves beyond Phase 1
in light of the announced delay to initiation of Phase 2 until
2018 time frame. Tell us if a final </b></p>

<p align="center">- 9 -</p>

<hr noshade>

<p style="page-break-before:always"><font size="2">&nbsp;&nbsp;</font></p>

<table border="0" cellpadding="0" cellspacing="0" width="100%">
    <tr>
        <td align="right" valign="top" colspan="2"><p
        align="right"><font size="1" face="Arial"><b><i>Eni
        S.p.A. has claimed confidential treatment of portions <br>
        of this letter in accordance with 17 C.F.R. &#167; 200.83</i></b></font></p>
        </td>
    </tr>
</table>

<p>&nbsp;</p>

<p><b>investment decision has been made for Phase 2. </b></p>

<p>The proved reserves of the Kashagan field remained undeveloped
for more than 5 years due to the time frame necessary to execute
a project of such a magnitude and technical and environmental
complexity. Development activities are progressing towards
completion and the production start up of Phase 1 is targeted by
the end of 2012.<br>
Our booked PUD reserves for the Kashagan project &#150; amounting
to 0.6 BBOE at 2010 year-end &#150; will be produced within the
limits of the oil processing capacity that is planned to be
available at the end of Phase 1. A small portion of such PUD
reserves will require limited additional development activity
intended to exploit the spare oil processing capacity which will
be available at end of Phase 1. The Final Investment Decision
related to Phase 2 has not yet been made.</p>

<p>&nbsp;</p>

<p><b>9. Please expand your discussion of the delay in developing
the Libyan gas fields. Include the figures for the associated PUD
reserves. </b></p>

<p>In future filings we plan to expand our disclosure about
Libyan gas fields and associated PUD reserves as follows:</p>

<p>&quot;Proved undeveloped reserves related to gas fields
located in Libya amounted to approximately 0.27 BBOE which have
remained undeveloped for more than 5 years as of end of 2010.
Development completion and production start up of those
undeveloped reserves is planned according to the delivery
obligations set forth in a long-term gas supply agreement
currently in force. In order to secure fulfilment of the
contractual delivery quantities, we plan phased production start
up from the relevant fields, which are expected to be put in
production over the next several years.&quot;</p>

<p>&nbsp;</p>

<p><b><u>Average Sales Prices and Production Cost per Unit of
Production, page 33</u></b></p>

<p><b>10. Item 1204 of Regulation S-K requires the disclosure of
historical price and cost data by geographical area. We note that
this data for equity accounted properties is not presented by
area. Please modify this in order to comply with Regulation S-K.</b></p>

<p>See our response to comment 5.</p>

<p align="center">- 10 -</p>

<hr noshade>

<p style="page-break-before:always"><font size="2">&nbsp;&nbsp;</font></p>

<table border="0" cellpadding="0" cellspacing="0" width="100%">
    <tr>
        <td align="right" valign="top" colspan="2"><p
        align="right"><font size="1" face="Arial"><b><i>Eni
        S.p.A. has claimed confidential treatment of portions <br>
        of this letter in accordance with 17 C.F.R. &#167; 200.83</i></b></font></p>
        </td>
    </tr>
</table>

<p>&nbsp;</p>

<p><b><u>Oil and gas properties, operations and acreage, page 35</u></b></p>

<p><b>11. Item 1208(b) of Regulation S-K requires the disclosure
of minimum remaining terms of material leases and concessions.
Please expand your disclosure to comply with Regulation S-K. </b></p>

<p>Please note that, where material, we disclosed the minimum
remaining terms of our material lease and concessions in the
section &quot;Oil and gas properties, operations and
acreage&quot; starting on page 34 of the 2010 Form 20-F when
describing operations in each country where the Group is active.
For example on page 47 we disclosed that the Kashagan PSA
contract will expire in 2041; the Karachaganak contract is due to
expire in 2037 as disclosed on page 48.</p>

<p>&nbsp;</p>

<p><b><u>Ecuador, page 51</u></b></p>

<p><b>12. We note the disclosure of &quot;volumes in place of 300
mmBBL&quot; and &quot;35 BBBL of certified heavy oil in
place&quot; on page 53. These figures do not represent reserves
and, as such, are not allowed in documents filed with us. Please
omit such disclosures from your future documents.</b></p>

<p>We will omit disclosure of amounts of resources which do not
represent reserves in our future filings.</p>

<p>&nbsp;</p>

<p><b><u>Exhibit 15.a(ii)</u></b></p>

<p><b>13. We note the third party engineering report presents
Africa and Asia average adjusted gas prices as $307.07/Mm3 and
$355.43/Mm3, respectively. Please affirm to us that these gas
prices are $8.68/MCFG and $10.05/MCFG. Tell us the properties and
the disposition of the gas associated with these prices. </b></p>

<p>As indicated in the &quot;Conversion table&quot; (page vi of
Form 20-F), 1 cubic meter of natural gas is equivalent to 35.3147
cubic feet of natural gas. Consequently, $307.07/Mm3 and
$355.43/Mm3 are equivalent to $8.69/MCFG and $10.06/MCFG
respectively. With respect to disposition of the gas associated
with these prices, the gas from Africa is destined to
Mediterranean Europe and the gas from Asia to LNG shipments to
the Far East.<br>
For the reasons indicated in or letter dated February 11, 2011 in
response to a prior comment from the Staff, the third party
engineering reports do not disclose prices relating to individual
properties, which is confidential information. </p>

<p align="center">- 11 -</p>

<hr noshade>

<p style="page-break-before:always"><font size="2">&nbsp;&nbsp;</font></p>

<table border="0" cellpadding="0" cellspacing="0" width="100%">
    <tr>
        <td align="right" valign="top" colspan="2"><p
        align="right"><font size="1" face="Arial"><b><i>Eni
        S.p.A. has claimed confidential treatment of portions <br>
        of this letter in accordance with 17 C.F.R. &#167; 200.83</i></b></font></p>
        </td>
    </tr>
</table>

<p>&nbsp;</p>

<p align="center">***</p>

<p>If you have any questions relating to this letter, please feel
free to call the undersigned at +39-02-520-41730.<br>
Eni acknowledges that it is responsible for the adequacy and
accuracy of the disclosure in its Form 20-F, that Staff comments
or changes to disclosure in response to Staff comments do not
foreclose the Commission from taking any action with respect to
its Form 20-F, and that Eni may not assert Staff comments as a
defense in any proceeding initiated by the Commission or any
person under the federal securities laws of the United States.</p>

<p>&nbsp;</p>

<p>&nbsp;</p>

<p>&nbsp;</p>

<table border="0" cellpadding="0" cellspacing="0" width="100%">
    <tr>
        <td width="70%">&nbsp;</td>
        <td width="30%">Very truly yours,</td>
    </tr>
    <tr>
        <td width="70%">&nbsp;</td>
        <td width="30%">&nbsp;</td>
    </tr>
    <tr>
        <td width="70%">&nbsp;</td>
        <td width="30%"><u>/s/ ALESSANDRO BERNINI</u> </td>
    </tr>
    <tr>
        <td width="70%">&nbsp;</td>
        <td width="30%">Alessandro Bernini</td>
    </tr>
    <tr>
        <td width="70%">&nbsp;</td>
        <td width="30%">Title: Chief Financial Officer</td>
    </tr>
</table>

<p align="center">- 12 -</p>

<hr noshade>
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`
end
</TEXT>
</DOCUMENT>
</SEC-DOCUMENT>
