Venezuela is one of the world’s largest exporters of crude oil and the largest in the Western Hemisphere. The oil sector is of central importance to the Venezuelan economy. As a founding member of the Organization of the Petroleum Exporting Countries (OPEC), Venezuela is an important player in the global oil market.
In 2008, Venezuela consumed 3.2 quadrillion British thermal units (BTUs) of total energy. Natural gas and oil represent the bulk of total energy consumption in Venezuela (see chart). Hydroelectricity, which plays a preponderant role in the Venezuelan power sector, accounts for the remainder of energy use. Over the last decade the share of oil consumption in the country’s total energy mix has risen from 32 percent to 44 percent, largely because the Venezuelan government subsidizes liquid fuels.
Venezuela was the world’s eleventh-largest net oil exporter in 2009.
According to Oil and Gas Journal (OGJ), Venezuela had 211 billion barrels of proven oil reserves in 2011, the second largest the world. This number constitutes a major upward revision – last year the same publication listed the country’s reserves at 99.4 billion barrels. The update results from the inclusion of massive reserves of extra-heavy oil in Venezuela’s Orinoco belt. Venezuela is a significant supplier of crude oil to the world market: in 2009 the country had net oil exports of 1.75 million barrels per day (bbl/d), eleventh-largest in the world and the largest in the Western Hemisphere. In recent years, crude oil production in the country has fallen, while domestic consumption has risen, causing a decline in net oil exports. EIA estimates the Venezuelan net exports fell again in 2010, to 1.59 million bbl/d.
Venezuela nationalized its oil industry in the 1970s, creating Petroleos de Venezuela S.A. (PdVSA), the country’s state-run oil and natural gas company. Along with being Venezuela’s largest employer, PdVSA accounts for a significant share of the country’s GDP, government revenue and export earnings. In 2002, nearly half of PdVSA’s employees walked off the job in protest against the rule of President Chavez, largely bringing the company’s operations to a halt. In the wake of the strike, PdVSA fired 18,000 workers – industry analysts speculate that the company never full recovered from the human capital impacts of this move.
During the 1990s Venezuela took steps to liberalize the petroleum sector. However, since the election of Hugo Chavez in 1999, Venezuela has increased public participation in the oil industry. The Chavez government initially raised tax and royalty rates on new and existing projects and mandated majority PdVSA ownership of all oil projects. In 2009 and 2010 Venezuela nationalized oil field service firms and infrastructure in response to these firms’ failure to renegotiate their contracts. Venezuela is also increasing pressure on foreign operators that remain in the country to increase investment to offset recent production declines.
Exploration and Production
EIA estimates that the country produced around 2.36 million bbl/d of oil in 2010. Crude oil represented 2.09 million bbl/d of this total, with condensates, natural gas liquids (NGLs) accounting for the remaining production. Estimates of Venezuelan production vary from source to source, largely due to measurement methodology. For instance, some analysts directly count the extra-heavy oil produced in Venezuela’s Orinoco Belt as part of Venezuela’s crude oil production. Others (including EIA) count the upgraded syncrude, which is about 10 percent lower than the volume of the original extra-heavy feedstock. EIA estimates that Venezuela’s crude oil production dropped again in 2010, to 2.09 million bbl/d. Natural decline at older fields, maintenance issues, and compliance with OPEC production cuts are behind this trend. Venezuela’s OPEC production target is currently 1.99 million bbl/d.
Venezuela’s conventional crude oil is heavy and sour by international standards. As a result, much of Venezuela’s oil production must go to specialized domestic and international refineries. The country’s most prolific production area is the Maracaibo basin, which contains slightly less than half of Venezuela’s oil production. Many of Venezuela’s fields are very mature, requiring heavy investment to maintain current capacity. Industry analysts estimate that PdVSA must spend some $3 billion each year just to maintain production levels at existing fields, given decline rates of at least 25 percent.
Orinoco Heavy Oil Belt
Venezuela contains billions of barrels in extra-heavy crude oil and bitumen deposits, most of which are situated in the Orinoco Belt in central Venezuela. According to a study released by the U.S. Geological Survey, the mean estimate of recoverable oil resources from the Orinoco Belt is 513 billion barrels of crude oil. PdVSA began the ‘Magna Reserva’ project in 2005, which involved dividing the Orinoco region into 27 blocks and quantifying the reserves in place. This initiative resulted in the upgrading of Venezuelan reserve estimates by more than 100 billion barrels.
In the 1990’s Venezuela established four strategic associations to exploit these resources, later converting them to mixed companies with majority PdVSA ownership. These projects involve converting the extra heavy crude and bitumen to lighter, sweeter crude, known as syncrude. The upgrading facilities themselves introduce another element of risk into Venezuela’s petroleum supply chain. While the country’s four upgraders have installed production capacity of about 600,000 bbl/d of syncrude, industry estimates place these projects’ production levels at less that 500,000 bbl/d due to maintenance and safety problems.
Venezuela plans to further develop the Orinoco Belt oil resources in the coming years. In 2009 Venezuela signed bilateral agreements for the development of four major blocks in the Junin area. Last year the country awarded two more major development licenses in the Carabobo region. Venezuela expects these projects to add more that 2,000,000 bbl/d of heavy oil production capacity by the end of the decade.
Venezuela was able to secure these recent agreements due to the minimal exploration risk Orinoco Belt projects entail. However, given recent regulatory and operational problems, considerable uncertainty surrounds the future of Orinoco production.
Venezuela’s petroleum exports have dropped by almost 50 percent, since peaking at 3.06 million bbl/d in 1997. Venezuela sends a large share of its oil exports to the United States because geographic proximity enhances export profitability and because refineries on the U.S. Gulf Coast are specifically designed to handle heavy Venezuelan crude. Currently, Venezuela is the United States’ fifth largest supplier of imported petroleum.
However, U.S. imports from Venezuela have declined in recent years. In 2010, the United States imported 987,000 bbl/d of crude oil and petroleum products from Venezuela, just 8.3 percent of total American imports. Even factoring in 255,000 bbl/d of imports from the U.S. Virgin Islands, which are almost exclusively petroleum products refined from Venezuelan crude, the significance of Venezuela to the American energy sector is in decline.
In recent years, Venezuela has attempted to diversify its export destinations away from the United States. Besides the United States, other important destinations of Venezuelan petroleum exports include the Caribbean, Europe and Asia. One of the fastest growing destinations of Venezuelan crude oil exports has been China. In 2010, China imported 125,900 bbl/d of crude oil from Venezuela, up from only 39,000 bbl/d in 2005.
Venezuela provides a sizable amount of crude oil and refined products to its regional neighbors at below-market prices and with favorable financing terms. Under the Petrocaribe initiative, Venezuela provides crude oil and refined products to numerous countries in the Caribbean and Central America, offering favorable financing and long repayment terms that often feature barter arrangements instead of cash transactions. In addition, Venezuela has a separate supply agreement with Cuba. According to industry reports, these preferential supply agreements amount to more than 400,000 bbl/d of Venezuelan exports.
According to OGJ, Venezuela had 1.28 million barrels per day (bbl/d) of crude oil refining capacity in 2011, all operated by PdVSA. The major facilities include the Paraguana Refining Center (940,000 bbl/d), Puerto de la Cruz (195,000 bbl/d), and El Palito (126,900 bbl/d). Through PdVSA and its subsidiary CITGO, Venezuela also controls significant refining capacity outside of the country.
The largest share of Venezuela’s global downstream operations is in the United States. CITGO, a wholly-owned subsidiary of PdVSA, operates three refineries (Lake Charles, LA; Corpus Christi, TX; Lemont, IL), with a combined crude oil distillation capacity of 755,400 bbl/d. CITGO’s gulf coast refineries source most of their crude oil with PdVSA under long-term supply contracts. PdVSA also owns a 50-percent stake in the 189,000-bbl/d Chalmette facility in Louisiana.
In 2009 ConocoPhillips’ exercised the option to purchase PdVSA’s share of their refinery in Sweeny, Texas. This move, coupled with Venezuela’s sale of its equity stake in Germany’s Rurh Oel to Rosneft, constitutes a substantial contraction of Venezuela’s net global capacity. Minor equity acquisitions in the Caribbean have partially offset this change. Venezuela plans to expand to other global refining markets. Notable planned refinery builds include and 400,000-bbl/d joint venture with PetroChina in Guandong province and a 230,000-bbl/d joint venture with Petrobras in northeastern Brazil.
Venezuela has the second-largest natural gas reserves in the Western Hemisphere.
According to OGJ, Venezuela had 179 trillion cubic feet (Tcf) of proven natural gas reserves in 2011, the second largest in the Western Hemisphere behind the United States. In 2009, the country produced 651 billion cubic feet (Bcf) of dry natural gas, while consuming 714 Bcf.
The petroleum industry consumes the majority of Venezuela’s gross natural gas production, with the largest share of that consumption in the form of gas re-injection to aid crude oil extraction. Due to the declining output of mature oil fields, natural gas use for enhanced oil recovery has increased by more than 50 percent since 2005.
In 1999, Venezuela adopted the Gas Hydrocarbons Law, which was intended to facilitate non-associated natural gas development and expand role of natural gas in Venezuela’s energy sector. This legislation allows private operators to own 100 percent of non-associated projects, in contrast to the ownership rules in the oil sector. It also mandates lower royalty and income tax rates on non-associated natural gas projects compared to oil projects. The law gives PdVSA the right to purchase a 35 percent stake in any project that moves into commercial status.
PdVSA produces the largest amount of natural gas in Venezuela, and it is also the largest natural gas distributor. A number of private companies also currently operate in Venezuela’s gas sector. Participants with significant assets include Repsol-YPF, Chevron, and Statoil.
Exploration and Production
An estimated 90 percent of Venezuela’s natural gas reserves are associated, meaning that they occur along with oil reserves. Currently, Venezuela is working to increase the production on non-associated gas, largely through the development of its offshore reserves. PdVSA has awarded exploration blocks in the Plataforma Deltana, Marsical Sucre, and Blanquilla-Tortuga areas off of Venezuela’s northeast coast and in the Gulf of Venezuela in the northwestern part of the country.
Offshore exploration has yielded numerous successful finds, including Repsol-YPF and Eni’s discovery of 6-8 Tcf of recoverable natural gas won the Cardon IV block in the Gulf of Venezuela – one of the largest natural gas discoveries in the history of the county. For Venezuela’s offshore gas development to move forward in a meaningful way, international partners will need to play a central role in production. PdVSA does not have experience in producing non-associated gas – the company’s most recent attempt at operating an offshore natural gas project resulted in the sinking of the Aban Pearl semi-submersible drilling rig in May 2010.
Pipelines and Liquefied Natural Gas
In recent years, Venezuela has improved its domestic natural gas transport network to allow greater domestic utilization and movement of natural gas production. The Interconnection Centro Occidente (ICO) system connects the central and western parts of the country, making natural gas more easily available for domestic consumers and for re-injection into western oil fields. Upon its scheduled completion on 2011, the ICO will have a capacity of 520 MMcf/d.
In 2008, the Antonio Ricaurte pipeline came online, connecting Venezuela with Colombia. Initially, the pipeline will allow Colombia to export natural gas to Venezuela, with contracted volumes ranging between 80 and 150 MMcf/d. Current plans then call for the flow of the pipeline to be reversed in 2012, with Venezuela exporting 140 MMcf/d of natural gas to Colombia.
In September 2008, Venezuela signed initial agreements to create three joint venture companies to pursue LNG projects along the northern coast of the country. Each project will consist of a separate liquefaction train with the capacity to export an estimated 101.3 Tcf per year. Although PdVSA signed contracts with a number of investors for these projects, it is not clear that adequate feedstock will be developed to meet their scheduled start date of 2014.
Like most South American countries, Venezuela depends upon hydroelectricity for the bulk of its electricity needs.
In 2008, Venezuela had 23.1 gigawatts of installed generation capacity. The country generated 123.4 billion kilowatthours of electricity in 2009, 70 percent of which was hydroelectric power. For most of the 2000s electricity consumption expanded at more than twice the rate of installed capacity, leaving the Venezuelan power grid stretched by the end of the decade. A major drought in 2009-2010 forced President Chavez to declare an “electricity emergency” and led the government to implement painful demand-reduction policies.
Large, state-owned companies dominate the electricity sector in Venezuela. The government controls the electricity sector through The National Electricity Corporation (CORPOELEC), a state-owned holding company created in 2007 to consolidate the power sector. CORPOELEC is responsible for the entire electricity supply chain, controlling all major electricity companies in Venezuela including Electrificacion del Caroni (EDELCA), which supplies around three-quarters of the country’s total electricity supply.
Hydroelectricity provides the bulk of Venezuela’s electricity supply. Most of the country’s hydro production facilities are located on the Caroni River in the Guayana region. The 8,900-megawatt Guri Hydroelectric Power Plant on the Caroni is one of the largest hydroelectric dams in the world and provides the majority of Venezuela’s electric power. Water levels at the Guri Dam dropped to record-low levels during the 2009-2010 drought, forcing the country to implement rolling blackouts, reduce industrial production, and fine large users for excessive consumption. Despite weather-related risks, Venezuela plans to expand hydroelectric production in the future.
Natural gas powers around one-half of the conventional thermal electricity generation in Venezuela; fuel oil and diesel power the rest. There has been increasing investment in conventional thermal capacity as a means to reduce reliance upon hydropower and utilize domestic hydrocarbon resources. PdVSA began generating power for its own consumption in 2010 to manage power-supply risks in the oil production sector. Especially in the case of conventional thermal generation from liquid fuels, expansion of conventional thermal generation capacity could further reduce Venezuela’s hydrocarbon exports.