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DCF-A /19 de Octubre de 2004
PEMEX Outlook
1DCF-A /October 19, 2004
Forward-looking Statement Disclaimer
This presentation contains forward-looking statements. We may also make written or oral forward-looking statements in our periodic reports to the National Banking and Securities Commission and the Securities and Exchange Commission, in our annual report, in our proxy statements, in our offering circulars and prospectuses, in press releases and other written materials and in oral statements made by our officers, directors or employees to third parties. Statements that are not historical facts, including statements about our beliefs and expectations, are forward looking-statements. These are good faith statements based on current plans, estimates and projections and therefore you should not place undue reliance on them. Forward-looking statements speak only as of the date they were made, and we undertake no obligation to update publicly any of them in light of new information or future events.Forward-looking statements involve inherent risks and uncertainties. We caution you that a number of important factors could cause actual results to differ materially from those contained in any forward-looking statement.
2DCF-A /October 19, 2004
Cautionary Note
The U.S. Securities and Exchange Commission (SEC) permits oil and gas companies, in their filings with the SEC, to disclose only proved reserves that a company has demonstrated by actual production or conclusive formation tests to be economically and legally producible under existing economic and operating conditions. We use certain terms in this document, such as total reserves, probable reserves and possible reserves, that the SEC's guidelines strictly prohibit us from including in filings with the SEC. Investors are urged to consider closely the disclosure in our Form 20-F, “File No. 0-99”, available from us at www.pemex.com or Marina Nacional 329 Floor 38 Col. Huasteca, Mexico City 11311 or at (52 55) 1944 9700. You can also obtain this Form from the SEC by calling 1-800-SEC-0330.EBITDA, free cash-flow and discretionary cash-flow are non-GAAP measures, which are calculated as described above. They are presented because PEMEX believes that they are widely accepted financial indicator of its ability to service or incur debt. EBITDA, free cash-flow and discretionary cash-flow should not be considered as indicators of financial performance, as an alternative to cash flow, as a measure of liquidity, or as being comparable to similarly named measures of other companies.The total debt calculation includes, in addition to documented debt, the items that are usually considered as debt by the financial markets.
3DCF-A /October 19, 2004
Agenda
PEMEX’s Highlights
Operations
Capex Program and Financial Profile
Challenges
4DCF-A /October 19, 2004
Pemex is the 8th Largest Integrated Oil Company in the World
Third largest producer of crude oil in the world(1)
Eighth largest integrated oil company in the world(1)
Proved reserves equivalent to more than 12 years of production(2)
Low cost producer vs. market average
Key supplier of crude oil to the US market
Mexico’s largest company with 2003 revenues of 57 billion dollars
Sole producer of crude oil, natural gas and refined products in Mexico
Sole marketer of refined products in Mexico
1) Based on PIW 2002 Rankings, December 2003, Petroleum Intelligence Weekly2) 2003 production levels and proved reserves in accordance with the definition under Rule 4.10(a) of
Regulation S-X under the U.S. Securities Act of 1933
5DCF-A /October 19, 2004
Integrated Oil Majors
Crude GasReserves
Crude GasProduction
Place Company Country Sales
1
2
3
4
5
6
7
8
9
10
Saudi Aramco
Exxon Mobil
PDVSA
NIOC
RD Shell
BP
Chevron Texaco
PEMEX
Total
Petrochina
Saudi Arabia
US
Venezuela
Iran
Netherlands & UK
UK
US
México
France
China
1
14
5
3
17
19
21
8
23
15
4
13
7
3
15
16
23
29
22
18
1
5
4
2
6
9
10
3
14
7
8
2
12
6
3
4
11
16
10
19
6
1
7
15
2
3
4
11
5
12
(1) (1)
Source: Petroleum Intelligence Weekly December 20031) Does not consider the reserves adjustments announced since January 2004
6DCF-A /October 19, 2004
Production Profile
3.1 2.9
3.43.23.13.03.0
1997 1998 1999 2000 2001 2002 2003
Crude oil production (MMbd)
4.8 4.84.54.44.5
4.74.5
1997 1998 1999 2000 2001 2002 2003
Natural gas production (MMMcfd)
1.5 1.5 1.61.51.51.41.5
1997 1998 1999 2000 2001 2002 2003
Refined products (MMbd)
Crude oil production has grown steadily since 1999
The decreasing trend of natural gas production has been reversed in 2003
Refined products production has increased slightly
7DCF-A /October 19, 2004
Crude Oil and Natural Gas Reserves
Long life of proven reserves of over 12 years and 3P life of 30 years based on 2003 production(2)
18.9
29.1
48.0
Proved Probable &Possible
3P(1)
Reserves as of December 31, 2003MMMboe
1) In accordance with the definition of proved reserves under Rule 4.10(a) of Regulation S-X under the U.S. Securities Act of 1933. Probable and possible reserves were obtained through the difference between 3P reserves and proved reserves. PEMEX filings with SEC only report proved reserves
2) Reserves as of December 31, 2003 and based on 2003 production (average daily production of 4.3 MMboed)
8DCF-A /October 19, 2004
Efficient Producer
2002 Lifting CostUS$/boe
2.33.0 3.3
3.8
5.1
6.6 6.7
0.01.02.03.04.05.06.07.08.0
Total Stat Oil BP ChevronTexaco
ExxonMobil
ConocoPhillips
Source: Herold and PEMEX
9DCF-A /October 19, 2004
Important Supplier of Crude Oil to the U.S.
PEMEX’s exports by region 2003(1)
U.S. Importsby region 2003(2)
100% = 1.8 MMbd 100% = 9.6 MMbd
18%
16%
17%12%
16%
21%
9%
3%
9%
79%
Saudi Arabia
Europe
Other Non-OPEC
VenezuelaOther OPEC
MexicoCanada
Rest of America
Far East USA
1) Source: PEMEX 2) Source: Energy Information Administration (EIA)
10DCF-A /October 19, 2004
EBITDA of the Major Integrated Oil Companies
EBITDA 2003MMMUS$
32.2 31.7
25.122.6
19.817.0
11.7 11.0 9.7
0.0
5.0
10.0
15.0
20.0
25.0
30.0
35.0
ExxonMobil
BP Total RD Shell ChevronTexaco
ConocoPhillips
Petrobras Stat Oil
Source: Bloomberg, excluding PEMEX
11DCF-A /October 19, 2004
PEMEX EBITDA 2003
8.4
23
3.6
31.7
3.50.324.3
47.3
55.7
MMMUS$
Total sales
Total sales net of IEPS
Costs and expenses
Operating income net
of IEPS
Other revenues
D&A(2) EBITDACost of the reserve(3)
IEPS(1)
(1) Special Tax on Production and Services(2) Depreciation and amortization(3) Cost of the reserve for retirement payments, pensions and indemnities
12DCF-A /October 19, 2004
PEMEX EBITDA 2003 reconciliation
MMMUS$
Net loss Taxes and duties
34.0 3.6-0.1
31.7
IEPS(1) CFC(2) D&A(3) Cumulative effect(5)
-3.6
-8.42.7
EBITDA
3.5
Cost of the reserve(4)
(1) Special Tax on Production and Services(2) Comprehensive financing cost(3) Depreciation and amortization(4) Cost of the reserve for retirement payments, pensions and indemnities(5) Cumulative effect due to the adoption of new accounting standards
13DCF-A /October 19, 2004
Agenda
PEMEX’s Highlights
Operations
Capex Program and Financial Profile
Challenges
14DCF-A /October 19, 2004
Untapped Exploration Potential
dd
Veracruz basin
Southeastbasins
Frente Sierra Madre Oriental
Tampico
Misantla
Deep-waterGulf of Mexico
Source: PEMEX
Burgos
Chihuahua
Sabinas
Sierra de Chiapas
Non productive basins
Macuspana
Productive basins
With non associated gas
Yucatánplatform
On-shore 1,923,040Continental shelf 263,259Deep-water 567,477TOTAL 2,753,776Non prospective 1,699,190Prospective 1,054,586
Basins explored 174,400% of basins explored 17
Area (km 2)
Prospective
15DCF-A /October 19, 2004
E&P Projects: Cantarell
Production 1996 2003 Increase
Crude oil (Mbd) 1,074 2,096 93%Associated natural gas (MMcfd) 443 770 74%
Largest oil field in Mexico and eighth largest in the world
2004 expected production: 2.1 MMbd of crude oil and 774 MMcfd of natural gas
Proved remaining reserves of 6.9 MMMboe
Recovery capability of 60% (world's average is 35%)
Cantarell facts
Year
Pressure and production
Nitrogeninjection Pressure
maintenance
Increase in production
The injection of nitrogen in Cantarell has slowed the pressure decline and increased production
Production
Pressure
16DCF-A /October 19, 2004
Revamping of Refineries
Crude Oil Refining Centers
5
5
5Salina Cruz5
Minatitlán
Tula5
5
CadereytaMadero
Salamanca
Refineries: 6Refining capacity (MMbd): 1.5
Modernization of the the refining system:
Main projects
Distribution (Maritime terminals modernization, SCADA)Production facilities (Lubricant plant in Salamanca, Minatitlán revamping)Gasoline (improvements in quality and mix of grades)
Increase in heavy crude processing capacityShift in product mix towards high octane gasolines and middle distillatesOptimization of the crude oil blend
Minatitlán refinery revamping is expected to be finished in 2007– Total estimated capex: MMMUS$2.4– Expected incremental production of gasolines: 97 Mbd– Expected incremental production of intermediate
distillates: 49 Mbd
17DCF-A /October 19, 2004
Expanding the Natural Gas Production Capacity
Gas Processing CentersPEMEX is investing to:
Increase import-export capacity (interconnections with the U.S.)
Enhance flexibility of transportation system
New projects:
nReynosa
n
Poza Rica
Cd PemexNuevo PemexCactus
Matapionche
Pajaritos
Morelos
nn
nn
n n
n
Cangrejera
La Venta
n
– New compression stations to increase the transport capacity in the area of Monterrey and Chihuahua
– Capacity expansion of the processing system in northern Mexico to capture natural gas liquids (4 cryogenic plants: 2 in 2004 and 2 more in the following years)
Sweetening Plants Capacity of 4,503MMcfd
Cryogenic Plants Capacity of 4,592 MMcfd
18DCF-A /October 19, 2004
Petrochemicals
Petrochemical centers Opportunities in the petrochemical process:
Investment in profitable petrochemical chains
New projects:5
5
5
5
55
Camargo
Tula
San Martín Texmelucan
Pajaritos
Cosoleacaque Cangrejera
Morelos5
5
Escolín – Expecting capacity expansions on the ethane chain in actual plants to gain domestic market share in the polyethylene business
– Seeking possible joint ventures with private sector in minority role companies to integrate the value chains
19DCF-A /October 19, 2004
Agenda
PEMEX’s Highlights
Operations
Capex Program and Financial Profile
Challenges
20DCF-A /October 19, 2004
Crude Oil and Natural Gas Production
Incremental Production
0
2,000
4,000
6,000
8,000
10,000
1993
1995
1997
1999
2001
2003
2005
2007
2009
0
1,000
2,000
3,000
4,000
5,000
1993
1995
1997
1999
2001
2003
2005
2007
2009
Crude oilproduction capacityMbd
Natural gas production capacityMMcfd
Historic Forecast
Historic Forecast Base Production
New Exploration Production
The oil industry requires large investments for maintaining and increasing reserves and production levels
Investment lags accumulate problems in the future
Source: PEMEX
21DCF-A /October 19, 2004
Historical and Projected CAPEX
PidiregasNon - Pidiregas
By type of projectMMMUS$
Note: Pidiregas: Long-term productive infrastructure projectsNon-Pidiregas: Budgetary InvestmentsP = Projected
3.1 2.6 3.0 3.0 2.2 1.7 1.0
2.0 2.94.5 3.9 5.6
8.411.0
1998 1999 2000 2001 2002 2003 2004P
5.1 5.5
7.56.9
7.8
10.1
12.0
22DCF-A /October 19, 2004
CAPEX 2004
By line of business
14%
86%
Exploration
Development11.1
0.10.3 0.5
E&PRefiningGas and Basic PetrochemicalsOthers
Total MMMUS$ 12 Total MMMUS$ 11.1
23DCF-A /October 19, 2004
EBITDA and Interest Coverage
EBITDA EBITDA / Interest
MMMUS$ Times15.2x
12.1x13.4x
0
2
4
6
8
10
12
14
16
2001 2002 2003
20.7 22.0
31.7
0
5
10
15
20
25
30
35
2001 2002 2003
Note: EBITDA net of sales taxes (IEPS). Interest expense does not include capitalized interest
24DCF-A /October 19, 2004
Debt-to-Reserves Ratio vs. Peers
Debt 2003 / Proved reserves
2.0
0.40.6
1.51.3
1.1
2.3
1.3 1.4
0.0
0.5
1.0
1.5
2.0
2.5
ExxonMobil
RD Shell Total BP ChevronTexaco
ConocoPhillips
Stat Oil Petrobras
Source: Companies’ financial statements as of December 31, 2003 and proved reserves data as of December 31, 2002 (other than PEMEX)1) Financial statements and proved reserves data as of December 31, 2003. Debt is the sum of documented debt, notes payable to
contractors and sale of future account receivable2) Does not consider the reserves adjustments announced since January 2004
US$ / boe
AAA AA
(1)
A B
(2)
25DCF-A /October 19, 2004
Credit Profile Relative to Integrated Majors
Exxon Mobil
BBB-Baa1
18.94.3
11.910.1
AA+Aa2
19.34.0
13.38.0
AA+Aa1
17.63.5
13.712.4
AAAAaa
21.74.2
14.012.9
AAAa2
11.22.4
12.78.4
AAAa2
11.92.6
12.45.6
A-A3
7.81.1
19.96.2
RD Shell
Total BP Chevron Texaco
ConocoPhillips
Ba2
10.51.8
15.95.7
Petrobras(1)
AA1
4.31.1
10.93.4
Statoil(3)
Senior Unsecured RatingsS&PMoody´s
Operating DataProven Reserves (MMMboe) (2)
Production (MMboed)(4)
Proven Reserves Life (years)CAPEX (MMMUS$)
Source: Bloomberg. Companies’ financial statements as of December 31, 2003 and proved reserves data as of December 31, 2002 (other than PEMEX)
1) EBITDA net of IEPS (special tax on production and services)2) PEMEX’s proved reserves in accordance with the definition under Rule 4.10(a) of Regulation S-X under the U.S. Securities Act of 1933. Data
as of December 31, 20033) Does not consider reserves adjustments announced since January 20044) When the conversion factor is not available, one million cubic feet of natural gas = 5.2 barrels of oil equivalent
26DCF-A /October 19, 2004
Agenda
PEMEX’s Highlights
Operations
Capex Program and Financial Profile
Challenges
27DCF-A /October 19, 2004
Challenges
Increase efficiencyFiscal regime proposalImplement corporate governance best practices
Challenges
28DCF-A /October 19, 2004
Challenges: Implementing Value Management Oriented to Efficiency
Implementing projects oriented to value creation
Implementing best practices in projects management
Optimization of plants and pipelines
Optimization of the procurement process
Value management for corporate (medical and telecommunications) services
Improving risk management
Implementing compensation according to performance
29DCF-A /October 19, 2004
Challenges: Fiscal Regime Proposal
New hydrocarbons should be taxed competitively according to fiscal regime in countries with similar geological conditionsOld hydrocarbons should be taxed in order to fit the short-term needs of the Mexican Federal Government
Old hydrocarbons
New hydrocarbons
Time
$
30DCF-A /October 19, 2004
Challenges: Implementing Corporate Governance Best Practices
Improve corporate governance
Continue to incorporate best practices:
– Independent board members
– Audit Committee
– Prompt disclosure of information
– Compensation based on performance
– Clear mandate to create value
Increased operational and financial autonomy
Arms length relationship with government
Improve transparency and credibility of the management process
PEMEX budget is part of the federal budget
Inefficient audit system
Legal restrictions for joint ventures
DCF-A /19 de Octubre de 2004