Global Energy Flow Tracker

Pipeline status is updated manually when significant news breaks — disruptions, sanctions, contract terminations. Commodity prices update in real time from market feeds. Pump fuel prices update weekly for EU countries (EU Oil Bulletin publishes every Monday) and monthly for others.

Ukraine declined to renew the transit agreement with Russia that expired on 1 January 2025, ending gas flows through the Brotherhood/Urengoy-Pomary-Uzhhorod pipeline that had operated for decades. Slovakia, Austria and Hungary were the most affected.

The Strait of Hormuz normally carries approximately 20-21 million barrels of oil per day — around 20% of global supply. In 2026, following Iranian military activity in the region, effective throughput has dropped significantly, contributing to Brent crude prices above $100/barrel.

Labels are hidden at the default zoom level to keep the map readable. Click on any pipeline to see its name, capacity and flow data. Zoom in to see country labels and facility icons appear progressively.

The Live Tankers tab embeds MarineTraffic's vessel map filtered to tanker vessel types, centered on key energy shipping regions including the Persian Gulf, Red Sea, Suez Canal and Mediterranean. MarineTraffic operates over 5,000 AIS ground stations globally.

Italy was one of Europe's most Russia-dependent gas consumers — in 2021 Russia supplied about 40% of Italian gas via the TAG pipeline through Austria at Tarvisio. After the 2022 invasion, Italy rapidly diversified: Eni signed new LNG and pipeline supply deals with Algeria, Libya, Egypt, Congo, Mozambique and Angola under its "Mattei Plan for Africa." The Tarvisio entry point now carries Azeri gas via the Southern Gas Corridor and Norwegian gas rather than Russian. Italy's gas demand dropped 19% from 2021 to 2024 as the economy and households switched fuels. Italy is also tripling its LNG regasification capacity from 16.1 bcm in 2022 to a planned 47.5 bcm by 2026 with four terminals now operational (Adriatic LNG/Rovigo, Panigaglia/La Spezia, OLT Toscana/Livorno, BW Singapore FSRU/Ravenna). The Adriatica Backbone pipeline from Puglia to Emilia-Romagna, currently under construction with a €300 million Ravenna–Chieti section completing in 2026, strengthens the South-to-North transport backbone for southern LNG and TAP gas flows, and is designed to be hydrogen-compatible.

The UK Continental Shelf (UKCS) is in accelerating decline. UKCS inflows to the National Transmission System could fall from around 30 bcm in 2024 to 20 bcm by 2030 — and 2025 saw the worst year for exploration on the UKCS since the basin began to be developed in the 1960s, with no exploration wells drilled at all. The Labour Government elected in 2024 pledged no new exploration licences. The Forties Pipeline System — which accounts for 35-40% of UK North Sea oil output — has seen throughput decline to around 216,000 b/d in 2024, down from its design capacity of 600,000+ b/d. Grangemouth refinery closed in 2025 and the Lindsey refinery owner entered administration, leaving only four operational refineries in the UK. The gas supply gap is being filled by LNG imports (South Hook at Milford Haven is one of the world's largest LNG import terminals, primarily supplied by Qatar) and increased Norwegian pipeline imports via Langeled.

Namibia is Africa's most exciting new oil frontier but has zero pipeline infrastructure yet — all production will be via FPSOs (floating production vessels) when it starts. TotalEnergies' Venus-1 discovery holds an estimated 2 billion barrels of oil, Africa's largest ever Sub-Saharan find. Galp's Mopane field has an estimated 10 billion barrels of oil equivalent following six consecutive successful wells. TotalEnergies pushed its final investment decision from 2025 to 2026, with first oil targeted for 2029. Shell wrote down $400 million on its Graff/Jonker discoveries citing reservoir permeability issues. The offshore markers show where these world-class discoveries are located. Botswana has no oil or gas pipeline infrastructure either — it imports all refined products from South Africa and is developing coalbed methane (CBM) resources in the Central and Northeast regions.

Egypt underwent a dramatic energy reversal. After the discovery of the Zohr megafield by Eni in 2015 (the largest gas discovery in the Mediterranean), Egypt briefly became a net gas exporter in 2020-2022. However, Zohr has suffered severe water infiltration since 2022, cutting output sharply. Egypt's LNG imports jumped 188% year-on-year during the first 11 months of 2025, reaching approximately 7.8 million tonnes, as domestic consumption exceeded production for the first time. Egypt deployed four FSRUs to handle the surge — at Ain Sokhna and Damietta — reaching 2.25 bcf/d regasification capacity. A $35 billion gas supply deal with Israel's Leviathan field (due to start in stages from 2026) will supply an estimated 10-11 bcm/year, feeding Egypt's idle LNG export capacity at Idku and Damietta for re-export to Europe.

Greater Tortue Ahmeyim is Africa's first offshore deepwater LNG project straddling the maritime border between Senegal and Mauritania. Operated by bp (56%), with Kosmos Energy, PETROSEN (Senegal) and SMH (Mauritania), Phase 1 achieved first gas in December 2024 and began commercial LNG exports in June 2025 at 2.5 mtpa capacity. A Hub Terminal sits on the shallow-water maritime border, receiving gas from a FLNG vessel in 2,850 metres of water. Phase 2 (adding 2.5-3 mtpa) has a pending FID with construction start expected 2028. This is a major breakthrough for West African gas — together with Senegal's Sangomar oil field (first oil 2024) it marks the emergence of new African Atlantic hydrocarbon exporters.

The Nigeria-Morocco Gas Pipeline (NMGP) is a $25 billion, 5,660 km proposed offshore and coastal pipeline that would connect Nigeria's gas through 13 West African coastal countries — Benin, Togo, Ghana, Ivory Coast, Liberia, Sierra Leone, Guinea, Guinea-Bissau, The Gambia, Senegal and Mauritania — to Morocco and onward to Europe via the Strait of Gibraltar. Topographic surveys for the northern section (Morocco, Mauritania, Senegal) are in advanced stages and tenders were relaunched in November 2024 with first phases (Nigeria-Ivory Coast and Mauritania-Morocco) targeting commissioning in 2029. This is a real, advancing project, distinct from the Trans-Saharan Gas Pipeline (Nigeria→Niger→Algeria, land route) which also signed new agreements in February 2025 with a 2026 construction start. Both pipelines reflect Europe's urgent need to replace Russian gas with African supply.

Tanzania holds an estimated 57 trillion cubic feet of natural gas reserves, most of it discovered since 2010 in deep offshore Rovuma Basin blocks. The Tanzania LNG project in Lindi would be the single largest investment in Tanzania's history at over $30 billion, involving Shell, Equinor, ExxonMobil, Pavilion Energy and others. However, the project has repeatedly been delayed — current timelines target FID around 2026-2027 with first LNG around 2031-2034. In the meantime Tanzania relies on the 542 km Mtwara-Dar es Salaam gas pipeline (commissioned 2015, Chinese-financed at $1.22 billion) which supplies natural gas from the Mnazi Bay and Songo Songo fields to power plants generating over 60% of the country's electricity. A 34.2 km Ntorya-Madimba pipeline with EPC contract signed July 2025 will bring the potentially large Ntorya field (estimated 20 Tcf) into the existing processing network, targeting completion Q3 2026. Malawi, landlocked immediately west of Tanzania and Mozambique, has no gas pipeline infrastructure at all and relies entirely on imported petroleum products trucked from Mozambique ports.

TAZAMA (Tanzania Zambia Mafuta) is a 1,710 km pipeline built in 1968 — sometimes called the "freedom pipeline" because it was built to free landlocked Zambia from dependence on oil routes through then-Rhodesia. It is jointly owned by the governments of Zambia (66.7%) and Tanzania (33.3%). Originally carrying crude oil, it was converted to diesel products in March 2023. In April 2025 Zambia launched an open access framework allowing competing oil marketing companies to use the pipeline, which cut local pump prices by 33% by August 2025. A feasibility study for a parallel 24-inch pipeline (the TZMPP) capable of 7 million metric tons per year — nearly double Zambia's 2030 projected demand — is now underway with a contractor selected. A separate Zambia cabinet-approved proposal would build a new pipeline from Walvis Bay, Namibia to Ndola carrying 350 MMcfd of gas for copper mining power generation, aligning with Aliko Dangote's supply plans from his Lagos refinery.

Angola LNG at Soyo is the world's first LNG plant supplied with associated gas — a byproduct of offshore oil production — rather than dedicated gas fields. The $12 billion, 5.2 mtpa plant (Chevron 36.4%, Sonangol 22.8%, Azule Energy/BP+Eni 27.2%, TotalEnergies 13.6%) shipped its 300th LNG cargo in 2024. A major breakthrough came in November 2025 when the New Gas Consortium (NGC) delivered first production from Quiluma and Maboqueiro — Angola's first ever non-associated gas project — adding up to 400 MMscfd of dedicated gas supply. Angola is considering an expansion of 3 mtpa to capitalise on growing Asian and European demand. A Lobito refinery (200,000 bpd) is under construction and a Congo River Canyon Crossing Pipeline — Chevron's largest ever well intersection at 2,000 feet below the seabed — was completed in 2024 to bring gas from Blocks 0 and 14 to the LNG plant.

Mozambique holds some of Africa's largest gas reserves — an estimated 100 trillion cubic feet in the Rovuma Basin — but the sector has been plagued by an Islamic State-linked insurgency in Cabo Delgado province since 2017. TotalEnergies declared force majeure on its 12.88 mtpa Mozambique LNG project in April 2021 and only lifted it in October 2025. ExxonMobil lifted force majeure on its $30 billion Rovuma LNG project in November 2025 with FID targeted for 2026 and first exports around 2030. The one success story is Eni's Coral Sul FLNG — Africa's first deepwater FLNG — which came online in October 2022, reached its full 3.4 mtpa plateau in 2025 and shipped its 100th LNG cargo in April 2025. FID was taken in October 2025 for Coral Norte FLNG (3.6 mtpa), a replica of Coral Sul, targeting first LNG in 2028. The map shows all four Mozambique LNG projects with their current status.

The CPMZ (Companhia do Pipeline Moçambique-Zimbabwe) Beira–Harare pipeline is Zimbabwe's only fuel import artery — a landlocked country with no oil production, entirely dependent on this single pipeline from the port of Beira to the Feruka depot near Harare. It currently moves around 3 million cubic metres per year of refined petroleum products and is being upgraded to 5 million m³/yr by 2027 with new pumping stations. Two major competing alternatives are proposed: a $1.5 billion Beira–Ndola (Zambia) pipeline signed in May 2025, and Aliko Dangote's $1 billion 2,200 km Walvis Bay–Botswana–Harare pipeline announced in November 2025 (using refined products from his Lagos refinery shipped to Walvis Bay). A separate onshore gas discovery by Invictus Energy at Mukuyu in northern Zimbabwe (Cabora Bassa Basin) could eventually reduce Zimbabwe's import dependency if commercialised.

South Africa faces an acute energy crisis known as the "gas cliff." Around 90% of South Africa's natural gas comes through the ROMPCO pipeline from Mozambique's Pande and Temane fields — an 865 km pipeline jointly owned by the governments of South Africa, Mozambique and Sasol. These fields are depleting rapidly, and in August 2023 Sasol announced it would cut off gas supply from June 2026 as reserves are exhausted. Industrial gas users directly employ around 70,000 people and contribute R300-500 billion annually to the SA economy. Transnet Pipelines is rushing to repurpose the Lilly Pipeline (Secunda–Durban) to carry LNG from a new import terminal at Richards Bay (Zululand Energy Terminal) as a replacement. The ROMPCO pipeline is shown on the map as partial/orange — critical infrastructure in sharp decline.

LNG Canada is a $47.9 billion LNG export facility at Kitimat, British Columbia — the largest private investment in Canadian history. Phase 1 began exporting in 2025, fed by the Coastal GasLink pipeline (670 km, commissioned November 2023) from the Montney/Duvernay shale gas formations in northeastern BC. Phase 2 would double capacity. It represents Canada's first LNG export terminal on the Pacific coast, competing with US Gulf Coast LNG for Asian markets. Woodfibre LNG (Squamish, BC) and Cedar LNG are both expected to add further Canadian Pacific LNG capacity around 2028.

The Trans-Alaska Pipeline System was designed for 2.1 million barrels per day when Prudhoe Bay was at peak production in the 1980s. Natural field decline has reduced throughput to around 463,000 barrels per day in 2025. Lower flow creates technical challenges — oil moves more slowly, cools more, and wax builds up. The pipeline celebrated pumping its 19 billionth barrel in September 2025. New North Slope developments including the Nuna project (online December 2024), Pikka, and the controversial Willow project are expected to partially reverse the decline, with Willow targeting first oil in 2029.

Both countries face acute gas shortages. Pakistan has a 2,000 MMcfd supply-demand gap — SNGPL and SSGC (the two Sui Gas companies) cover 8,900 km and 3,551 km of transmission respectively, but domestic Sui field production has declined significantly. Pakistan now imports large volumes of RLNG through two LNG terminals at Port Qasim in Karachi. Bangladesh similarly faces depletion: Titas and Habiganj fields decline 5-7% annually, and 30-40% of supply is now imported LNG through two FSRUs at Moheshkhali. The Chittagong-Bakhrabad pipeline (commissioned 2020, ADB/AIIB funded) was specifically built to move regasified LNG from the coast to the national grid.

Japan is unique in having no national gas transmission system operator (TSO) and no interconnected national trunk pipeline. Gas networks developed separately around each of Japan's 37 LNG import terminals due to the country's mountainous archipelago geography. Each major city region — Tokyo, Nagoya, Osaka, Fukuoka, Sapporo — has its own isolated network. Japan imports 100% of its natural gas as LNG and has no cross-border pipeline connections with any country. This is shown on the map as isolated regional pipeline segments around the major LNG terminal clusters.

North Korea has no significant oil or gas pipeline infrastructure. The country runs almost entirely on coal (approximately 73% of energy supply), supplemented by hydropower and limited fuel oil imports. North Korea has no cross-border pipeline connections and is completely isolated from regional energy networks, including any connection to Russia, China or South Korea.

Cambodia and Laos currently have no operational oil or gas pipeline infrastructure. Cambodia relies on diesel generators, coal, hydro and imports from neighbours. Its first LNG power plant (Koh Kong, 900 MW) broke ground in October 2024 with an LNG import terminal planned for 2027. Laos is known as the "Battery of Southeast Asia" — it exports hydropower electricity to Thailand, Vietnam, China and Cambodia, but has no domestic oil or gas production or pipeline network.

No. This is an independent project built with publicly available data from EIA, IEA, European Commission, Global Energy Monitor, and market data feeds. It has no commercial affiliations with energy companies, pipeline operators or trading firms.

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Pipeline infrastructure data is complex and some regional flows are difficult to verify precisely. If you spot an error — wrong route, incorrect status, missing pipeline — we welcome corrections. The goal is the most accurate freely available global energy infrastructure map.