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CONTENTS
1. SUMMARY
2. HISTORY:- THE OIL CENTURY
2.1. Oil Demand
2.2. Oil Supply
2.3. Oil Price
2.4. Control
3. COMPANIES
4. BP plc
4.1. BP Upstream
4.2. BP Performance
5. INVESTMENT IN PETROLEUM
5.1. Exploration and Appraisal
5.2. Field Development
5.3. Transportation
5.4. Refining
5.5. Distribution
5.6. Upstream Investment
11Introduction
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LEARNING OBJECTIVES
Having worked through this chapter the Student will be able to:
General
1 Describe general financial aspects of the petroleum industry
History
2. Describe briefly the nature and evolution of demand for oil
3. Describe briefly the evolution of oil supply
4. Describe two situations where an attempt was made to control the market for
petroleum
Companies
5. Explain how the role of the National Oil Company versus the International
Petroleum Company has changed since 1974
BP plc
6. Describe briefly the history of the company
7. Describe briefly the Foinaven project
8. List ten financial parameters or statistics that may be used to explain or to monitor
the performance of a petroleum company
9. Describe five of these statistics or parameters
Investment in Petroleum
10. List and describe the five principal sectors of petroleum activity
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11Introduction
1. SUMMARY
This module concerns the economic evaluation of petroleum projects. It does not
prescribe a particular method or process, but rather focuses on ideas and principles,
which may become incorporated into corporate procedure. Petroleum investment is
subject to considerable risk and attracts much attention from government. Some of
these issues are identified and reviewed.
Chapter Two concerns the idea of an “asset”, as something possessing value or
bestowing value on its owner. Methods of quantifying such value are considered.
Chapter Three introduces the concept of the “time value of money”, the idea that
money received or spent at different points in time may have different perceived value.
The process of discounting derives directly from this idea and forms the basis of much
systematic study of investment value.
Chapter Four explains the method of cash flow analysis and identifies a number of
important parameters, which may be derived. These measures of value have
important applications, with respect to property trade and project investment.
Chapter Five reviews the diversity and significance of government involvement in the
petroleum industry.
Chapter Six reviews the risk environment, within which petroleum investment ismade.
Chapter Seven identifies and explains some of the important procedures, which may
be used to reduce or to quantify risk. These form the basis of risk management.
2. HISTORY:- THE OIL CENTURY
Detailed study of the history of petroleum business is beyond the scope of this module.
However, it is important for anyone, who is entering the industry, to take an interest.
It is a fascinating story, with an extensive literature. As an introduction and forbackground information, Appendix Three contains a chronological summary, an
edited account of 4000 years of wealth creation, risk and intrigue. If you require more
detail, find a copy of “The Prize” by Daniel Yergin, it is comprehensive and very
readable. Alternatively, use the Internet, which has become an amazing source of
information. Appendix Four is an introductory list of useful URL’s. You should
quickly compile your own.
Although some of the major petroleum companies originated before 1900, most of the
significant events in the history of petroleum belong to the 20th century. In fact, such
has been the growth and dominance of the industry over the last 100 years, that it is
difficult to argue with the suggestion that the 20th Century was truly the oil century.
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2.1. Oil Demand
In 1900, the world traded around 500 million tonnes of oil equivalent in energyproducts, 95% as solid fuel and 5% as oil. 100 years later, the energy market had
expanded almost twenty fold and petroleum [oil and gas] had acquired more than 60%
of this market. Figure 1 plots the growth in energy commodities and Figure 2 indicates
the market share gained by the petroleum industry.
0
1000
2000
3000
4000
5000
6000
7000
8000
9000
10000
60 80 1900 20 40 60 80 2000
Nuclear + Hydro
Natural Gas
Crude Oil
Solid Fuel
0
10
20
30
40
50
60
70
60 80 1900 20 40 60 80 2000
Figure 1
World energy 1860-2001
million tonnes oil
equivalent
Figure 2 Petroleum market share
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11Introduction
Table 1
Petrol Consumption
Figure 3
World car population
This trend reflected a number of factors:-
(i) The petroleum industry was increasingly successful at finding petroleum and
in manufacturing a wider range of useful refined products.
(ii) Fluids are easier to handle than solids
(iii) Transportation technology was increasingly based on oil products [internal
combustion, jet, marine engines].
(iv) Economies of scale reduced the price of oil in relation to other fuels.
(v) Economic and military systems became progressively dependent.
One of the significant factors has been the growth in use of motor vehicles. Figure
3 is a logarithmic plot of cars in use, versus time. The current population is around
650 million worldwide. The illustrative calculation in Table 1 indicates petrol
consumption of the order of 17 million barrels per day, almost one quarter of total
petroleum production.
0.01
0.1
1
10
100
1000
1900 1910 1920 1930 1940 1950 1960 1970 1980 1990 2000
m i l l i o n s
25 average fuel consumption [miles per US gallons]?10,000 average annual distance per vehicle [miles]?400 average annual consumption per vehicle [US gallons]9.52 average annual consumption per vehicle [barrels]
650 m world car population
6188 m annual petrol consumption [barrels]16.95 m daily petrol consumption [barrels]
Note:- data approximate and not confirmed
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Figure 2 reveals that this exponential trend was terminated in the early 1970’s, when
oil price suddenly increased. Since 1975, the market for gas, always seen as secondaryto oil, has been growing faster. Figure 4 indicates that from 1970 to 2000, gas
production increased by a factor of 220%, ahead of oil at 158%. This trend reflects
increasing awareness of environmental issues. Combustion of gas produces less
greenhouse gas emission, than does the combustion of refined products of oil.
1.00
1.25
1.50
1.75
2.00
2.25
70 75 80 85 90 95 2000
Oil
Gas
P r o d u c t i o n r e l a t i v e t o 1 9 7 0
2.2. Oil SupplySupply of oil has grown, both in quantity and geographical diversity. Around the
beginning of the 20th Century, output was less than half a million barrels per day, with
USA and Russia sharing 95% of the market. By 1945, output had grown to 7 million
barrels per day and USA had become undisputed market leader, producing more than
65% of world supply. Most of the rest was controlled by six countries, including
Venezuela, Russia and Iran. See Figure 5.
0.1
1
10
100
1000
10000
1865 1875 1885 1895 1905 1915 1925 1935 1945
Venezuela 1922
Persia 1908
Mexico 1905
East Indies 1885
Russia 1860
Rumania 1860
USA 1859
Others
T h o u s a n d B a r r e l s p e r d a y
Figure 4
Growth in petroleum
production
Figure 5
World oil production
[logarithmic].
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11Introduction
Figure 6
Regional oil production
[million bopd]
For almost 30 years post World War Two [WW2], oil production increased
exponentially to around 65 million bopd, as a result of prolific discoveries in theMiddle East and elsewhere, stimulated by ever-greater demand for petroleum-based
energy products. The ten-fold price increases between 1973 and 1981 disrupted this
trend and caused the market to hesitate, then slide back, until halted by a price collapse
in 1986. Following these price discontinuities, the upward trend continues. BP now
lists 48 countries with at least 50,000 barrels per day. Figure 6 illustrates this growth
in volume and diversity. [See also Table 3, Chapter 5, for a list of the top forty
petroleum-producing countries].
00
25
50
75
1950 1960 1970 1980 1990 2000
Middle East
Russia / FSU
Asia Pacific
Europe
South America
Africa
North America
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2.3. Oil Price
The average price of oil is plotted in Figure 7. Data is presented, both as dollars spent“money of the day” and as dollars in relation to value in the year 2000, “2000 terms”.
See Chapter 3 Section 9.4 for a full explanation of this terminology.
0
10
20
30
40
50
60
70
80
90
100
Price [$/bb/ mod]
Price [$/bbl 2000]
60 80 00 20 40 60 80 00
Price has shown dramatic fluctuations over time, reflecting changes in the market.
Supply disruption, shortage and uncertainty causes price to increase; exploration
success or economic depression may cause the price to fall. Note the increase
associated with war, or its aftermath and with political discontinuity:- WW1 [1914-
18], WW2 [1939-45], Yom Kippur [1973], Iranian Revolution [1979]. Note the fall
associated with success:- Spindletop [1901], East Texas [1930], Libya etc [1960’s],
North Sea and Mexico [1980’s].
2.4. ControlPetroleum is a unique business:-
The products are singularly useful for modern economic and military systems.
Production and processing is highly capital intensive.
Investment carries considerable risk.
Distribution of resources is uncertain.
Investment may be undermined by exploration success elsewhere.
Competition and profitability are therefore unpredictable.
Various attempts have been made over the years to control elements of the market, in
order to reduce costs, competition and investment risk.
Figure 7
Crude oil price $/bbl
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11Introduction
Table 2
Standard Oil
a) Standard Oil
Standard Oil was established by John D Rockefeller in 1870, as a refining company.
It was a successful business and used aggressive and, sometimes, questionable tactics
to undermine the competition. Growth was accelerated by acquisition and the
company achieved complete domination, particularly of the downstream business in
North-East USA. Headquarters in New Jersey and a new corporate “Trust” structure
were used to circumvent Federal laws relating to inter-State ownership. In 1911, after
years of legal dispute, the Trust structure was finally outlawed and Standard was split
into more than 30 separate companies, three of which became “majors” and several
became leading “independents”. Some of the detail of Standard and its subsidiary
companies is presented in Table 2.
1882 SO New Jersey > SO New Jersey > 1972 Exxon > ExxonMobil
1888 Anglo American > Anglo American 1930 ^ 1951 Esso UK
1882 SO New York > Socony 1966 Mobil 1998
1866 Vacuum Oil 1879 Vacuum Oil 1931 ^
1908 BP
1870 Standard Oil > SO Ohio > Sohio 1987 ^
1885 Solar Refining Solar Refining 1931 ^
1889 SO Indiana > SO Indiana > 1973 Amoco 1998 ^
1906 SO Nebraska > SO Nebraska 1939 ^
1896 SO Kansas > SO Kansas 1950? ^
1866 Atlantic Refining 1874 Atlantic Refining > 1966 Arco 1999 ^
1879 Pacific Coast Oil 1900 Socal > 1984 Chevron 2001 > ChevronTexaco
1886 SO Kentucky > SO Kentucky [1984 Gulf]
1875 Continental Oil 1884 Continental Oil > 1929 Conoco 2002 > ConocoPhillips
1887 Ohio Oil 1889 Ohio Oil Company > 1962 > Marathon
1907 Shell
1889 South Penn Oil > South Penn Oil Pennzoil 2002 ^
1881 National Transit > National Transit 1965
1881 SW Penn Pipelines 1905 SW Penn Pipelines 1952 ^
Eureka Pipeline Eureka Pipeline 1947 ^
1924 Ashland
Cumberland Pipeline Cumberland Pipeline 1931 ^
Southern Pipeline Southern Pipeline 1949 ^
1901 Galena-Signal Oil Galena-Signal Oil 1959 ^
plus 13
The grey column represents Standard Oil. To the left are component parts, date of
origin and date of takeover by Standard. Some of these names are of companiescreated by Standard, sometimes to amalgamate pre-existing business. To the right is
the outcome of the break-up of the Trust. 34 companies were created, 21 are listed.
Of the remainder, some were taken over and some became bankrupt. Moving to the
right, the columns indicate takeover, merger and change of name, with dates where
possible. Note that, for completeness, BP, Shell and Ashland are included. They
were not part of Standard itself, but now own parts of the outcome.
b) Red Line Agreement
Turkish Petroleum was established in 1912, to seek petroleum concessions in the
Middle East. The company was inspired by Calouste Gulbenkian, an Armenianentrepreneur, who had been convinced for many years of the prospectivity of
Mesopotamia [Iraq]. Ownership became a source of considerable political, as well
as commercial interest and, on the insistence of the British Government, Anglo
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Persian was included in 1914, see Table 3. After WW1, politics changed and German
interests [Deutsch Bank] were replaced by the French [CFP]. There followed a longperiod of international negotiation, culminating in the formal inclusion of an American
syndicate [SO New Jersey, SO New York and others] in 1928. Figure 8 is a cartoon
from this time, indicating a British-French carve-up, with an American “foot in the
door”.
These companies, with the support of government, were signatories to the so-called
“Red Line Agreement”. This related to an area encompassing the Arab Peninsula and
northwards to the Black Sea, the Ottoman Empire as was in 1914. See Figure 9 for
a map of the relevant area. The basis of the agreement was that the signatories would
not compete with each other within this designated area. This agreement, involving
the world’s largest companies of the day, set the pattern for later negotiation.
1912 1914 1928
Gulbenkian 7.5% 5% 5%
Royal Dutch Shell 25% 22.5% 23.75%
Deutsch Bank 25% 22.5%
National Bank of Turkey 42.75%
Anglo Persian 50% 23.75%Compagnie Francaise des Petroles 23.75%
American Syndicate 23.75%
Figure 8
San Remo 1920
Table 3
Turkish [Iraq] Petroleum
Company Equity
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11Introduction
Figure 9
Red Line area
In the meantime, Turkish Petroleum negotiated a concession with the Iraq government
in 1925 and made a huge discovery at Baba Gurgur in 1927. The name of the company
soon changed to Iraq Petroleum [IPC]. Gulbenkian became known as “Mr Five
Percent”.
c) Achnacarry Agreement
The oil industry in 1928 faced a number of serious problems, including overcapacity
and falling prices. In August, the chief executives of Standard New Jersey, Standard
Indiana, Anglo Iranian, Shell and Gulf gathered to shoot grouse at Achnacarry, in theScottish Highlands. They also found time to discuss matters of business and reached
an agreement, known as the “Pool Association”. Under this agreement, the cartel
decided that:-
i Companies would share production and markets on the basis of the balance then
prevailing
ii New facilities would be constructed only as necessary and to supply in the most
efficient manner
iii Price would be on a “Gulf Plus” basis, meaning that price would be based on
USA export price, with transportation charges as if the oil originated from the
Gulf of Mexico
These clauses formed the basis of inter-company agreement in Europe and parts of
Asia for the next twenty years.
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d) Organisation of Petroleum Exporting Countries [OPEC]
During the 1950’s, the market for oil expanded rapidly, with major new discoveries
in the Middle East, North Africa and elsewhere. Most of this production was under
the control of a small number of large, international companies [the “Majors” or
“Seven Sisters”]. The companies had Concessions or production licences which
afforded power and freedom to explore and to develop. Re-entry of the Soviet Union
into this market around 1955 added to the growing problem of over-supply and caused
an inevitable, downward pressure on prices.
Oil price was based on a formal system of “Posted Prices”, from which Royalties and
Taxes were derived. Posted Price had originally matched market price, but in the
market of the late 1950’s, companies had been discounting price to maintain marketshare. With a fixed Posted Price [and taxes] and a falling, selling price [and revenue],
companies found themselves paying a higher proportion to government, [see Figure 10].
0
1
2
3
4
50 51 52 53 54 55 56 57 58 59 60 61 62 63 64 65 66 67 68 69 70 71 72 73 74
Posted
Market
$11.6511/1/74
D o l l a r s p e r B a r r e l
Companies had the legal right to change Posted Price, but used this sparingly. In 1959,
BP cut its Posted Price by 18¢ [about 10%]. The producer countries were angry and
the issue was discussed at the Arab Oil Congress, held in Cairo in 1959. The
immediate outcome was an informal, “Gentlemen’s Agreement” concerning the
following issues:-
i defence of the existing price structure
ii formation of national oil companies
iii increase in tax-take beyond 50 – 50iv development of downstream industry
Figure 10
Saudi Arabian light
fob Ras Tanura
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11Introduction
Figure 11
Production ratios
[proportion of 1973]
The following year, after further cuts in Posted Price, representatives of leading oil
producers met in Baghdad and OPEC was formed. The founder members were:-Saudi Arabia, Iran, Iraq, Kuwait and Venezuela. Formation of OPEC was the first
collective act of sovereignty exercised by oil producers, with the following objectives:-
i to restore price to pre-cut levels
ii consultation on pricing issues
iii creation of a mechanism for production regulation
iv solidarity in the face of potential, individual sanctions.
In the early years of the organisation, market over-supply limited its powers.
However, in 1960, its market share of world-traded oil was 80% and rising. When
the market tightened in the early 1970’s, OPEC was in a position to exploit the
situation, to increase price. See Appendix 3 and Chapter 6, Section 5.4. OPEC has
survived for more than 40 years and still carries considerable influence. All cartels,
however, face problems both within and without. Controlling production requires
discipline on the part of its members; increasing the price creates extra profits for all
market participants and inevitably encourages expansion of production outside the
control of the cartel. Figure 11 indicates how regional production evolved after the
1973 price increases. Note that Middle East production fell by 50% by 1985, in the
face of mounting competition from Russian, Mexican and North Sea production.
0.5
1
1.5
2
2.5
1973 1978 1983 1988 1993 1998
North America
South America
EuropeFormer Soviet UnionMiddle EastAfrica
Asia Pacific
3. COMPANIES
In 1973, seven large companies, the “Seven Sisters” controlled more than sixty
percent of world oil production. Today, these four [amalgamated] organisations have
little more than ten percent of the market. Table 4 indicates how the market has
changed. The OPEC inspired intervention, which took place in the mid-1970’s,resulted in a massive transfer of control, from international to national oil companies
[NOC’s]. Of the top twenty producers, listed in Table 4, half are NOC’s. The top
four are all NOC’s and are responsible for about 25% of the market. Limited access
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to foreign companies is available in some of the countries, where the resource in
controlled by an NOC. In UAE for example, ADNOC has a 60% interest in key joint
venture companies.
Current 2000 1973 Origin
Saudi Aramco 9.1 1974 NOC:- Saudi ArabiaNIOC 3.8 1953 NOC:- IranPemex 3.5 1938 NOC:- MexicoPDVSA 2.8 1975 NOC:- VenezuelaExxonMobil 2.5 7.9 1882 Merger in 1999RD Shell 2.3 4.5 1892 Merger in 1907
KPC 2.2 1974 NOC:-Kuwait, merged 1980Petrochina 2.1 1988 Privatised by CNPC in 1999ChevronTexaco * 2.0 10. 1902 Includes Gulf; merger 2001BP 1.9 4.6 1908 Includes Amoco, Arco, SohioADNOC 1.5 1971 NOC:- UAE [60%]TotalFinaElf * 1.5 1920 Final merger 1999Lukoil 1.5 1991 Privatised in 1993Sonatrach 1.4 1963 NOC:- AlgeriaYukosSibneft * 1.3 1993 Privatised in 1994Petrobras 1.3 1953 NOC:- BrazilPDO 0.8 1967 part nationalised 1974ConocoPhillips * 0.8 1875 Merger 2002ENI 0.8 1953 NOC:- Italy; privatised 1995 >Statoil 0.7 1972 NOC:- Norway; p priv 2001
Repsol-YPF 0.6 1986 Acquisition in 1999 World Total 74.5 44.0Seven Sisters 11.7% 62.7%
* These companies merged after 2000; the data reflect separate companiesin 2000
The Seven Sisters had to re-invent themselves. BP, in 1972, sourced 99% of its oil
supplies from the Middle East and North Africa. Today these countries contribute
very little [to BP]. Loss of oil supply and dramatically increased oil price provided
the incentive and a favourable economic environment for exploration and developmentof new areas, some of which were considerably more expensive than the lost
productive capacity in the Middle East. The North Sea and Alaska, for example, have
both been developed since 1973 and both represent order of magnitude increases in
cost. Companies have also evolved by merger and acquisition, “drilling on Wall
Street” as they say. Appendix Three lists some of this activity under “1980’s” and
“1999”. Merger also creates opportunity for economies of scale and other cost savings.
Table 4
Oil production by company
[million bopd}
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11Introduction
Table 5
Petroleum in reserve
[end 2000]
Oil Gas O + G world cum
bbls 10^9 boe 10^9 boe 10^9 %
Saudi Aramco * 261.8 38.1 299.9 15.1 15.1
NIOC * 89.7 144.9 234.6 11.8 26.8
UAE * 97.8 37.9 135.7 6.8 33.7
Iraq * 112.5 19.6 132.1 6.6 40.3
Gazprom 122.0 122.0 6.1 46.4
KPC * 96.5 9.4 105.9 5.3 51.7
PDVSA 77.7 26.2 103.9 5.2 57.0
Sonatrach * 9.2 28.5 37.7 1.9 58.9
Pemex * 26.9 5.4 32.3 1.6 60.5
ExxonMobil 11.6 9.3 20.9 1.0 61.5
RD Shell 9.7 9.4 19.1 1.0 62.5
BP 7.6 7.4 15.0 0.8 63.2
Lukoil 14.2 0.7 14.9 0.7 64.0
Yukos 11.8 0.5 12.3 0.6 64.6
ChevronTexaco 8.5 3.0 11.5 0.6 65.2
TotalFinaElf 7 3.8 10.8 0.5 65.7
PDO * 5.5 5.2 10.7 0.5 66.3
Petrobras * 8.5 1.4 9.9 0.5 66.8
ConocoPhillips 5 2.7 7.7 0.4 67.2
ENI 4 2.6 6.6 0.3 67.5
Repsol-YPF 2.4 2.4 4.8 0.2 67.7
Statoil 2 2.3 4.3 0.2 67.9
* national reserves
Table 5 presents reserve data and another challenge. The top ten international
companies report oil and gas reserves, which represent about 6 percent of the world
total. At current rates of production, these companies would be depleted in fewer than
15 years. Half the recorded world reserve is under the control of the six largest NOC’s.
Access to this will depend on how the politics of world oil evolves, but at present
equity access is limited. One anomaly in this equation is Gazprom, a private
company, [Russian Government owns 38% of shares], with control over most of
Russia’s gas resource. It is clearly one of the largest, both in terms of reserves and
production.
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If size equates with success, petroleum is a successful business. Table 6 lists the
fifteen largest companies worldwide, ranked by sales in 2001, according to FortuneMagazine. Five of these are oil companies, including ExxonMobil and BP in the top
four. Furthermore, four other companies in the list specialise in motor vehicle
manufacture, one of the most important markets for oil products.
Company $ Billions
Walmart Stores 219.8
ExxonMobil 191.6
General Motors 177.3
BP 174.2
Ford Motor 162.4Enron 138.7
Daimler Chrysler 136.9
Royal Dutch Shell 135.2
General Electric 125.8
Toyota Motor 120.8
Citigroup 112.0
Mitsubishi 105.8
Mitsui 101.2
ChevronTexaco 99.7
TotalFinaElf 94.3
4. BP plc
BP is one of the former Seven Sisters and one of top three international petroleum
companies. Like most of the large petroleum companies, it has a century of history
and has grown both by successful investment in upstream and downstream facilities
and by acquiring or merging with other companies. See Table 7 for a simplified time-
line, summarising BP historical evolution. Since 1974, the larger companies have
found it easier to grow by merger and acquisition, than by exploration and development.
[See Section 3 above, Chapter Seven, Section 3.2 and Appendix 3 for further
information.]
BP is a vertically integrated petroleum company, meaning that it is involved in the
whole process, from exploration, through to marketing of refined and manufactured
products.
BP has upstream [exploration and production] interests in more than twenty countries,
most of which are listed in Tables 8 and 9. The UK and USA dominate, with sixty
percent of current production. In the midstream [transportation] business, BP has a
significant interest in three world-class, million-barrel-per-day pipeline systems. The
Forties Pipeline in the North Sea carries production from more than forty fields and
generates tariff income of some $350 million per year. The Alaska pipeline was vital
to the successful development of the North Slope and the new Baku-Tblisi- CeyhanPipeline will create a valuable, alternative route for export from the Caspian Basin.
Downstream [refining, manufacturing and marketing], BP has 24 refineries, 38
Table 6
Fortune 500 [2001]
Top Earning Companies
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11Introduction
chemical sites and almost 30,000 service stations. It sells 6.6 million barrels of
petroleum products and 100,000 tonnes of chemicals every day.
4.1. BP UpstreamTable 8 is a breakdown of BP oil production in 2002 with a more detailed listing of
oilfields in the UK. Oilfields commonly produce economic volumes of gas and some
of these named oilfields also contribute to the natural gas production recorded in Table
9. Bruce, for example is a complex field with reserves of oil, condensate and gas. In
2002, Bruce produced 45,000 barrels of oil and 450 million cubic feet of gas per day.
Many petroleum development projects are owned by a group, rather than by a single
company. Bruce, for example, has four participants, as follows:-
43.25% TotalFinaElf
37.00% BP
16.00% BHP Billiton
3.75% Marubeni
Joint ownership reflects the strategy of spreading risk, particularly at the time of
exploration [see Chapter Seven, Section 3.1]. BP’s percentage interest is noted for
each of the named fields. As fields mature, investment risk diminishes and companies
may seek to rationalise their interests. Having a larger, percentage share of a smaller
number of projects is probably more efficient use of resources. Furthermore, larger
companies may be more suited to the development of new opportunities and maytherefore wish to transfer mature assets to smaller organisations, which specialise in
such projects. In the UK, in recent years, BP has disposed of ten fields, which are
approaching abandonment. Forties, for example, has been sold to Apache in 2003.
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1901 Persia D’Arcy Concession, funded by Burmah
1908 Masjid-i-Suleiman, Persia Oil discovery1909 Anglo Persian Ltd Formation of new company, by Burmah1909 Abadan, Persia New refinery [to become world’s largest]1914 UK Government Purchase majority shareholding1914 Iraq Petroleum Company Joint Venture company1920 Scottish Oils [shale oil] Acquisition1924 Grangemouth New refinery1928 Baba Gurgur, Iraq Oil discovery [Iraq Petroleum Joint Venture]1931 Shell Mex & BP Joint Venture company1935 Anglo Iranian Ltd Name change1938 Burgan, Kuwait Oil discovery [Gulf JV] [50000 million bbls]1951 Iran Nationalisation of petroleum assets1954 British Petroleum Ltd Name change1954 Iran New Concession, includes British Petroleum
1956 Niger Delta, Nigeria Oil discovery [Shell Mex Joint Venture]1969 Forties, UK Oil discovery [2750 million bbls]1970 Sohio Acquisition of shares1977 Alaska Completion of Trans-Alaskan Pipeline System.1987 Sohio Acquisition of remaining shares1987 UK Government Share disposal1988 Britoil Acquisition1991 Cusiana, Colombia Oil discovery [1600 million bbls]1996 Mobil Downstream Joint Venture1998 Amoco Merger [60:40]1998 BPAmoco plc Name change1999 Arco Acquisition2000 Trinidad Gas discoveries2000 Burmah Castrol Acquisition
2001 BP plc Name change2002 Veba Oil Acquisition2002 Caucasus Agreement to build Baku-Tblisi-Ceyhan Pipeline2003 Sidanko, TNK Russia Joint Venture company
The fields, which are named in Table 8, are all BP-operated, meaning that BP is the
group member with responsibility for field planning, construction and operation. See
Chapter Five, Section 3.7 for information about the role of the Operator. One of these
BP-operated fields is Foinaven, which was the first to receive development consent
in deep water on the UK Atlantic margin. Summary technical details of this project
are listed in Table 10 and the field development is illustrated in Figure 12. Cash flowdata from Foinaven are introduced in Chapter Two, Section 6, and then used to
demonstrate evaluation methodology throughout Chapter Four.
Table 7
BP plc Time Line
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11Introduction
Oil Production
10^3 bopd
Angola 29
Argentina 53 BP Interest BP Share
Australia 43 % 10^3 bopd
Azerbaijan 38
Canada 16 62.8 23
Colombia 46 37.0 17
Egypt 85 72.0 72
Norway 84 96.1 50
Russia 73 70.0 42
Trinidad 67 50.0 10
UAE 113 100.0 16
UK 461 85.0 31
USA Alaska 309 62.1 7
USA GOM 264 52.0 11
USA Lower 48 192 69.9 1
Venezuela 51 69.9 37
Other 94 33.4 33
67.8 32
Σ 2018 Other various 79
UK Field
Names
Andrew
Bruce
Foinaven
Forties
Harding
Loyal
Machar
Magnus
Marnock
Miller
Monan
Mungo
Schiehallion
Wytch Farm
Gas Production
10^6 scfd
Argentina
Australia
Canada
China
Egypt
Indonesia BP Interest BP ShareNetherlands % 10^6 scfd
Norway
Trinidad various 28
UAE various 169
UK 75.2 113
USA Alaska 100.0 106
USA GOM 82.3 47
USA Lower 48 43.5 48
Other 41.0 54
73.7 63
Σ various 601
70.5 108
various 2094
3431
US Fields
BP Operated
Anscutz Ranch East
Hugoton
Jonah
Marlin
Matagorda Island 519
Matagorda Island 623
Moxa Arch
Pompano
San Juan Coal
Wamsutter
Non-operated
251
295
514
102
256
45787
60
1238
134
1550
52
1185
2246
280
8707
Table 8
BP Oil Production 2002
Table 9
BP Gas Production 2002
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Location Atlantic Margin, Faroes Basin 160 Km West of the Shetland Islands Water depth 500 metres
Ownership 72% BP28% Marathon
Licence 1985 Concession
Discovery 1992Consent 1994Onstream 1997
Reservoir Palaeocene sandsOil gravity 25-26 APIºReserves 323 million barrels of oil
221 billion cubic feet of gas
Production Two sub-sea production manifoldsSub-sea water and gas injection
FPSO.Export Shuttle tankers Gas pipeline to Magnus
4.2. BP PerformanceBP is a “large” and “successful” company, operating in a large and dynamic market.
There are many parameters, which may be used to describe corporate activity and to
measure corporate performance. The following notes refer to data in Table 11, which
are extracted from BP Annual Accounts, 1997-2002.
Table 10
Foinaven Summary
Figure 12
Foinaven Field
Development
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11Introduction
Section “a” indicates key elements of the economic environment, within which
BP operates, with weak prices in 1998 and strong prices in 2000. As
an international company, BP trades in many currencies and is
inevitably affected by exchange rates. Refinery margin [surplus of
revenue over operating costs] reflects supply and demand interaction
in that market.
Section “b” highlights operational details. Reserves replacement is a measure of
exploration success; greater than 100% means discoveries exceed
production. Finding and development cost records the unit cost of
new fields and reflects geographical location, technological advance
and corporate efficiency. Production of oil was uniform over this
period, whereas gas production increased significantly from 1999.
Section “c” includes measures of financial activity. Turnover is a measure of
company sales revenue; it reflects variation in prices and in rates of
production. Capital investment is money spent on new projects. It
fell in 1999, in response to lower prices and revenues in the previous
year. $36 billion was spent in acquiring Arco in 2000. Finance Debt
is money borrowed from banks and financial institutions and for BP
represents about 25% of its available capital. Increased borrowing
increases corporate risk [see Chapter Six, Section 5.7].
Section “d” relates to performance. Measures of profitability, as published incorporate accounts, must conform to recognised accounting standards.
In the UK, for example, procedures are contained in Financial
Reporting Standards [FRS’s] and Statements of Recommended
Practice [SORP’S]; in the USA, Generally Accepted Accounting
Principles [GAAP’s]. Historical Cost Profit is the standard,
accountants’ measure of performance [see Chapter Two, Section 2];
here, it correlates strongly with prices. Return on Average Capital
Employed [ROACE] is profit, as a proportion of capital employed [a
measure of total corporate funding]. Dividend is the annual distribution
of profit to shareholders; note that Dividend distribution was preserved
in 1998, despite lack of profit, a measure of the influence of the large,institutional investors, which hold most of the BP shares. Share price
reflects market perception of the performance and potential of the
company. It also reflects attitude to the stock market in general and
to other forms of investment.
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Table 11
BP Statistics
1997 1998 1999 2000 2001 2002
a) BP average oil price $/bbl 18.30 12.10 16.74 26.63 22.50 22.69
BP average oil price £/bbl 11.16 7.29 10.33 17.64 15.63 15.13
BP average gas price $/mcf 2.50 1.93 1.92 2.91 3.30 2.46
BP Refinery Margin $/bbl 2.50 2.10 1.24 4.22 4.06 2.11
Exchange Rate $/£ 1.64 1.66 1.62 1.51 1.44 1.50
b) Reserves replacement % 160.00 132.00 112.00 163.00 191.00 175.00
Find / Dev Cost $ / bbl 4.22 4.70 3.21 3.29 3.68 4.14
Oil production bopd 10^6 1.93 2.05 2.06 1.93 1.93 2.02
Gas production boepd 10^6 1.03 1.00 1.04 1.31 1.48 1.49
Employees 100,800 96,650 80,400 107,200 110,150 115,250
c) Turnover $ 10^9 108.60 83.70 101.20 161.80 175.40 180.19
Capital Investment $ 10^9 9.70 9.00 6.40 11.00 13.20 14.07
Acquisitions $ 10^9 1.00 0.70 0.30 36.40 0.90 5.04
Finance Debt $ 10^9 12.87 13.76 14.54 21.19 21.42 22.01
Taxation $ 10^9 4.00 2.69 3.34 8.71 8.06 5.62
d) Historical Cost Profit $ 10^9 5.30 2.70 4.60 10.10 6.60 6.85
Ave. Capital Employed $ 10^9 50.67 51.30 52.04 78.84 87.26 89.62
ROACE % 0.10 0.05 0.09 0.13 0.08 0.08
Net Income per boe $ 4.25 2.08 4.17 8.61 7.51 6.04
Dividend $ 10^9 3.50 4.10 3.90 4.60 4.90 5.38
Share Price 31/12 £ 4.00 4.49 6.22 5.40 5.34 4.27
Dividend per Share £ 0.11 0.12 0.12 0.14 0.15 0.16
5. INVESTMENT IN PETROLEUM
BP currently produces 2 million barrels of crude oil and sells more than 6 million
barrels of refined products every day. In order to maintain productivity and operating
efficiency, the company invests, annually more than $10 billion in new field
development, downstream facilities and infrastructure. The world petroleum
industry invests in excess of $100 billion per year. See Table 12 for data on ten large
international companies.
Turnover Capex Upstream$ 10^9 $ 10^9 %
ExxonMobil 232.7 11.2 62RD Shell 191.5 9.6 57ChevronTexaco 117.0 9.5 66BP 168.7 11.0 60TotalFinaElf 105.4 7.7 69Lukoil 13.4 1.6 68Yukos 9.8 1.4ConocoPhillips 66.2 4.8 77
ENI 48.8 5.0 62Repsol-YPF 43.2 6.1
Σ 996.7 67.9
Table 12
Sales and investment [2000}
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11Introduction
From exploration, through to selling a gallon of gasoline, the petroleum industry
consists of a number of business layers, as illustrated in Table 13. Expenditure isdivided into two categories, namely Capital and Operating.
Capital
Expenditure
Operating
Expenditure Taxation Profit Price per Barrel
f)
Excise Duty &Sales Tax none none
Excise Duty &Sales Tax none
$90 - $190
Gasolineselling price
e)
Distribution &Marketing
Storage facilities
Transportation fleetService station
System operationSales Corporate Taxes Downstream Profit
$50
Gasoline
selling pricepre-duty
d)Refining Refinery Refinery operation Corporate Taxes Downstream Profit
$44
Gasoline marketprice ex-refinery
c)Transportation
Pipeline system
Tanker fleetTerminals
Tariff payments
Pipeline operationTanker operation Corporate Taxes Midstream Profit
$27Market price cif
b)
Field
Development &Operation
Production platform
Production wells
Control equipmentExport system Field operation
Production Taxes
RoyaltiesCorporate Taxes Upstream Profit
$25Market price fob
a)
Exploration &Appraisal
Successful Wells
Seismic surveys
Exploration wellsLogging/ test ing Unsuccessful Wells
Signature BonusAllowances none
$2Finding Cost
(a) Exploration and appraisal
(b) Field development and operation
(c) Transportation
(d) Refining
(e) Distribution and marketing
Capital Expenditure [Capex] relates to the creation of a useful or productive system
and equates with “invests” above. Operating Expenditure [Opex]is that required to
operate and to maintain these productive systems. See Chapter Two, Section 4.1 for
a more detailed explanation.
5.1. Exploration and AppraisalExploration is the first stage in the process of producing oil. Money is spent on seismic
surveys and drilling of exploratory wells. Discoveries are made, tested and eventually
added to reserves. Many unsuccessful wells are drilled. Standard practice is to
consider the cost of successful wells as Capex and the cost of unsuccessful wells as
Opex. This is known as “successful efforts” accounting. It is, however, permissable
to record all exploration expenditure as Capex [full cost accounting]. This is
explained more fully in Chapter Two, Section 2.2.
Table 13
Investment in oil
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Taxation is limited at this stage, since revenue is not generated. Lump sum payments
[Bonus Bid or Signature Bonus] may be required by the Licence agreement [SeeChapter Five, Section 3.3]. Expenditure gives rise to tax allowances, which may be
carried forward, until revenue is available.
Finding Cost relates exploration expenditure to barrels discovered. This depends on
a wide range of factors, such as geological complexity, well location and technology.
Time is a particular problem in compiling any average relationship between reserve
barrels and cost of discovery, since commercial status may not be confirmed for five
or ten or twenty years. Because of varying calculation procedure, it is difficult to use
such a parameter to make meaningful comparison between companies.
5.2. Field DevelopmentOnce a commercial decision is taken, investment [Capex] is required in wells,structures, production facilities and export. The cost of development varies dramatically
from one environment to another [onshore – deep offshore] and technology evolves
over time. Order of magnitude differences are possible. Development cost per barrel
is influenced by many factors [see Chapter Two, Section 5.3] and may be calculated
in a variety of ways [see Chapter Four, Section 4.2]. and so caution is required with
interpretation and comparison.
When production starts, expenditure [Opex] is required to operate the system, in order
to produce petroleum. Opex per barrel is sometimes called “Lifting Cost”; this
benefits from economies of scale and increases over time as rate of production
diminishes.
Taxation varies from country to country and many regimes include specific field-
related, or upstream or production taxes. The basis of these taxes is normally the
market price for crude oil. If a field or petroleum project can be delineated, it is
possible to define profit, relating to it. Profit is generally based on the residual of crude
oil selling price less exploration, development and lifting costs, and taxes.
“Upstream” relates to the discovery and the production of oil and gas. “Downstream”
relates to refining and manufacture of chemical products. The transition is some
convenient point of sale, which may be the wellhead, an offshore loading buoy or an
export terminal. The price at this point is identified as “fob” meaning “free onboard”. The transportation phase between upstream and downstream may be called
“midstream”.
5.3. TransportationTransfer from oilfield to refinery may be direct, by pipeline, or by a series of stages
and owners involving pipeline, storage and tanker. The Forties Pipeline System, for
example, runs directly to the Grangemouth Refinery in Central Scotland. It also links
to an export terminal, which allows part of the stream to be exported to Europe and
North America, by tanker Transportation infrastructure may be owned by the user [oil
producer], or leased on a per- journey, per-year or per-barrel basis. Ownership implies
that the company has invested [Capex], whereas leasing implies payment of tariffs[Opex].
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11Introduction
Transportation from wellhead to point of sale [or valuation], may fall within the
boundary [ring fence] of upstream or production taxes, whereas transportation beyondthat point does not. The cost of the midstream journey is reflected in the difference
between the delivered price [cif meaning carriage insurance and freight] and the fob
price. This midstream transportation activity is subject to general corporate taxes
[wherever the company is based] and contributes to general corporate profits.
5.4. RefiningRefineries buy crude oil at market [cif] price; [if the refinery is owned by the oil
producer, this “transfer” price may differ from market price]. Refineries are designed
to produce a range of refined products and therefore generate revenue reflecting the
weighted-average, market price of these products. The difference between unit
selling and unit purchase price is sometimes called the gross refining margin. This
is the revenue available, per barrel, to meet refinery operating costs and also give a
return on the capital investment . [Net] refinery margin is gross margin minus refinery
operating cost [energy plus materials plus labour etc]. Detailed analysis of refinery
economics is beyond the scope of this module. Refinery activity gives rise to general
corporate taxes and profits.
5.5. DistributionRefinery output may be feedstock for other downstream processes, or may be
transferred directly into a distribution system for sale to consumers. All the large oil
companies have access to service stations selling gasoline [petrol, benzene], their
most important product. Service stations may be owned by an oil producer and refiner,
by a refiner or by a retail organisation. If the retailer is independent of the refiner, the
product is purchased on a wholesale market.
Sales Tax; Tax is commonly charged on gasoline at the point of sale. This may be
called duty, excise duty, sales tax or value added tax. It is a proportion of pre-tax
selling price. In the USA, these taxes amount to some $20 per barrel, whereas in the
UK, $140 per barrel, bringing the selling price of gasoline close to $200 per barrel.
5.6. Upstream InvestmentLarge, integrated petroleum companies invest predominantly in the upstream sector
of the business. It is expensive, it is long term and it is risky, but it may be very
profitable. A single exploration well can cost anything from less than $1 million tomore than $100 million, with perhaps a 75% chance of failure; an oilfield development
can cost from a few to a few thousands of millions of dollars and may then generate
revenues for half a century. Financial performance of a company is derived directly
from its investments, the larger the project and the longer its life expectancy, the more
important the decision.
Decisions to make these investments are always taken in an environment of uncertainty.
Recoverable reserves are only confirmed, when they have been recovered and
technology often has to survive in extreme conditions. Tomorrow, the price of oil will
be different and somewhere government policy will have changed.
Chapters, which follow, consider the principles of investment in general, and review
the specific issues of upstream petroleum investment, in an environment of uncertainty.
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