Russia supplies a significant volume of fossil fuels to other European countries. In 2021, it was the largest exporter of oil and natural gas to the European Union, (90%) and 40% of gas consumed in the EU came from Russia. In July 2025, the largest European importers of Russian fossil fuels were Hungary, France, Slovakia, Belgium and Spain. The Russian state-owned company Gazprom exports natural gas to Europe. It also controls many subsidiaries, including various infrastructure assets. According to a study published by the Research Centre for East European Studies, the liberalization of the EU gas market drove Gazprom's expansion in Europe by increasing its share in the European downstream market. It established sale subsidiaries in many of its export markets, and also invested in access to industrial and power generation sectors in Western and Central Europe. In addition, Gazprom established joint ventures to build natural gas pipelines and storage depots in a number of European countries. The dependency on Russian fossil fuels poses energy security risks for Europe. In a number of disputes Russia used pipeline shutdowns, which motivated the European Union to diversify its energy sources. The rapid expansion of renewables in the European energy market would allow for less imports. As a reaction, Russia is expanding its export abilities towards China, as it has only one pipeline. The 2022 Russian invasion of Ukraine caused the Russia–European Union gas dispute. The European Commission and International Energy Agency presented joint plans to reduce reliance on Russian energy, reduce Russian gas imports by two thirds within a year, and completely by 2030. In May 2022, the European Union published plans to end its reliance on Russian oil, natural gas and coal by 2027. In the wake of Russian invasion of Ukraine, Russia's role in the EU energy market has collapsed. Due to EU sanctions, Russia's weaponization of gas supplies, and the sabotage of the Nord Stream pipelines, Russia delivered only around 60 BCM of gas to the EU in 2022. By contrast, in 2021, the EU imported 155 BCM of Russian gas, which accounted for about 45% of its total gas imports. If the pipeline flows remain at current levels, it is likely that Russia will supply around 25 BCM of piped gas to the EU over the course of 2023.
History
The Druzhba pipeline to supply allies in the Eastern Bloc was put into operation in 1964. The Urengoy–Pomary–Uzhhorod pipeline was constructed in 1982–1984. It complemented the transcontinental gas transportation system Western Siberia-Western Europe which existed since 1973. The official inauguration ceremony took place in France. In February 1978, an agreement was made to transport 13.6bn. cubic metres of gas from the Soviet Union to Western Europe, through Czechoslovakia, partly to replace gas from Iran after the Iranian Revolution. In the early 1980s there were American efforts, led by the Reagan administration, to convince European countries, through which a proposed Soviet gas pipeline was to be built, to deny firms responsible for construction the ability to purchase supplies and parts for the pipeline and associated facilities. Ronald Reagan feared that a Kremlin-controlled European natural gas pipeline infrastructure would increase the USSR's influence not only in Eastern Europe, but also in Western Europe, as planned by the Soviet Falin-Kvitsinsky Doctrine.
For this reason, during his first term in office, Reagan attempted – unsuccessfully – to stop the first natural gas pipeline from being built between the USSR and Germany. The pipeline was built despite these protests and the rise of large Russian gas firms such as Gazprom as well as increased Russian fossil fuel production has facilitated a large expansion in the quantity of gas supplied to the European market since the 1990s. Since the 2000s, natural gas pricing in Europe has gradually shifted from fairly stable long-term contract pricing largely linked to the price of oil, which supported the large-scale investments in developing gas fields and pipelines, to competitive market based pricing. This change was driven by EU regulation, moving from a 30% market price share in 2010 to 80% in 2020, saving EU countries an estimated $70 billion over the 2010s largely driven by the development of cheap U.S. shale gas. However, due to the 2021 global energy crisis, the International Energy Agency estimated the total cost of EU gas imports in 2021 will be about $30 billion higher that year than it would have been under the previous pricing regime. In September 2012, the European Commission opened formal proceedings to investigate whether Gazprom was hindering competition in Central and Eastern European gas markets, in breach of EU competition law. In particular, the Commission looked into Gazprom's usage of 'no resale' clauses in supply contracts, alleged prevention of diversification of gas supplies, and imposition of unfair pricing by linking oil and gas prices in long-term contracts. The Russian Federation responded by issuing blocking legislation, which introduced a default rule prohibiting Russian strategic firms, including Gazprom, to comply with any foreign measures or requests. Compliance is subject to prior permission granted by the Russian government. In 2013 the shares of Russian natural gas in the domestic gas consumption in the EU countries listed were:
Gas for northern Europe largely came from the Nadym Pur Taz (NPT) region in Western Siberia, but these large fields are now in decline due to depletion. Since the early 2010s Gazprom has been developing replacement gas fields in the Yamal Peninsula area of the Russian Arctic. As of 2020, Yamal produces over 20% of Russia's gas, which is expected to increase to 40% by 2030. The shortest pipeline routes from Yamal to the northern EU countries are the Yamal–Europe pipeline through Poland and Nord Stream 1 to Germany. During the winter peak Gazprom does not have the capacity to redirect flows to the central pipeline corridor through Ukraine, built for the NPT gas flow. Gazprom intends to decommission some pipelines, over forty years old with high maintenance costs, in the central corridor as NPT production declines.
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