August 2020, Vol. 247, No. 8


2020 Midyear International Outlook: Pipeline Construction & Market Trends

By Jeff Awalt, Executive Editor 

The COVID-19 crisis has dramatically affected oil and gas production and demand, leaving no midstream markets untouched as drilling screeched to a halt, pipeline projects were sidelined and global storage neared capacity in a stark reversal of trends at the start of 2020.

As the pandemic continued to rage into midyear and economies sputtered to restart, projections seesawed week to week and the outlook for demand recovery remained hazy.

Work continues along Enbridge’s Line 3 despite some regulatory snarls along the way. (Photo: Enbridge)

Market Trends

The International Energy Agency (IEA) predicted in July that producer supply cuts will help return global oil markets to more stable footing by the end of the year, with demand rebounding in 2021 by a record 5.3 MMbpd to 97.4 MMbpd, despite an estimated 7.9 MMbpd decline in 2020 to 92.1 MMbpd.

Earlier estimates had forecast a more severe impact, but oil demand during the second quarter bounced back more than many analysts expected. IEA, for one, revised its forecast upward by 400,000 bpd in July but warned of ongoing risks: “While the oil market has undoubtedly made progress, the large, and in some countries, accelerating number of COVID-19 cases is a disturbing reminder that the pandemic is not under control, and the risk to our market outlook is almost certainly to the downside.” 

The U.S. Energy Information Administration (EIA) cautiously reset average oil price expectations higher in its July forecast while bracing for the potential impact of lingering – even elevating – numbers of coronavirus cases in some regions. It predicted average 2020 prices for West Texas Intermediate (WTI) at $37.55/bbl (+6.9% vs. June) and Brent crude at $40.50 (+6.5%). For 2021, it expects WTI to average $45.70 and Brent $49.70, (+4.1% and 3.8% over June, respectively).

Natural gas has so far experienced a less severe impact than oil, but it has not been immune. “The record decline this year represents a dramatic change of circumstances for an industry that had become used to strong increases in demand,” said Fatih Birol, IEA’s executive director. 

Worldwide natural gas demand this year is expected to fall by 4%, or 5.30 Tcf (150 Bcm) – twice the size of the drop following the 2008 global financial crisis, according to IEA’s “Gas 2020” report. For the full year, more mature markets across Europe, North America and Asia are forecast to see the biggest drops, accounting for 75% of the total decline. 

Natural gas prices have remained low as reduced demand has so far outweighed lower production, but consensus estimates point to upward price pressure later in 2020. EIA forecasts the benchmark Henry Hub spot price will average $2.46 per MMBtu in the fourth quarter of 2020, bringing the full-year average to $1.93/MMBtu. In 2021, it expects lower production to push the average to $3.10.

In developed regions, demand for crude oil pipeline construction should continue to track upstream production trends, largely driven by U.S. shale and conventional upstream projects in the Middle East and Russia. Demand for natural gas pipelines, meanwhile, will be influenced by a more complex range of factors, many of which are region-specific.

Developing regions such as China and India have committed to expanding their natural gas import and distribution infrastructures as they wean themselves off coal, and low natural gas prices provide incentive for ongoing pipeline construction. But reduced economic activity, even in these faster-growing regions, has dampened demand, resulting in a supply glut that may slow the expansion of LNG export infrastructure elsewhere in the world.

North America

The global plunge in oil and gas demand abruptly halted a surge of pipeline construction activity in the United States, where operators were answering demand created by a decade of record-shattering shale production and soaring exports.

U.S. operators have scaled back or deferred crude oil projects to the tune of at least 1.5 MMbpd since the lockdown began to seriously impact oil prices and production in April. Announced delays include the Phillips 66/Plains All American Red Oak and Liberty pipelines and the Enterprise Products Partners Midland-to-Echo 4 pipeline. Phillips 66 Partners also deferred a final investment decision on its ACE Pipeline project and the planned expansion of its Sweeny Hub fractionation capacity.

“Midstream companies are somewhat reticent about canceling projects or announcing delays, so the number of such announcements has been limited,” notes Morningstar Analyst Sandy Fielden, who looks for projects that have either passed their planned start-up dates or are listed without completion dates in EIA’s pipeline database. 

Based on those indicators, the list of impacted construction projects includes the 650-mile (1,046-km), Permian-to-Brownsville Jupiter Pipeline, Marathon’s 600,000-bpd Swordfish Pipeline in Louisiana and the Plains/Delek 150,000-bpd Red River expansion.

Legal and regulatory challenges to major pipeline projects have steepened the decline in construction activity. In July, Dominion Energy and Duke Energy canceled their long-delayed, $8 billion Atlantic Coast natural gas pipeline, a project that would have delivered Marcellus Basin natural gas to the U.S. Southeast. Earlier, Williams put its Northeast Supply Enhancement natural gas pipeline on hold after New York environmental regulators denied a key water permit and canceled the proposed Constitution natural gas pipeline from Pennsylvania to New York after years of opposition.

A plan to roughly double the capacity of the 570,000-bpd Dakota Access crude oil pipeline (DAPL) was proceeding through the approval process in early 2020, but the fate of both the expansion and the existing pipeline came into question in July when a federal court ordered it to be shut down and emptied due to a purportedly faulty environmental permit. Energy Transfer is appealing the order.

Construction of TC Energy’s Keystone XL crude oil pipeline was delayed by a court ruling, upheld by the U.S. Supreme Court in July, requiring additional environmental review. The Calgary-based company said it remains “fully committed” to the 830,000-bpd project and will look at alternatives if the U.S. permit is not reinstated, such as pursuing individual permits for different pipeline segments and route adjustments.

There was a silver lining to the U.S. Supreme Court ruling, however, as it also reinstated the U.S. Army Corps of Engineers’ fast-track permitting program known as Nationwide Permit 12 for other projects. That decision removed a roadblock that threatened to delay more than 70 pipelines across the United States and add up to $2 billion in costs, according to industry estimates.

Canada’s Supreme Court also made rulings in 2020 benefiting pipeline construction projects, including one that ended seven years of legal challenges to the Trans Mountain pipeline expansion. Now under construction, that project will triple the capacity of the 67-year-old pipeline from Alberta to the British Columbia Coast. Completion is slated for late 2022.

TC Energy’s Coastal GasLink pipeline also resumed construction in Western Canada after a positive ruling earlier in the year. The $5 billion (C$6.6 billion) project will move gas 416 miles (670 km) from Northeast British Columbia to the Pacific Coast, where the Shell-led LNG Canada export facility is under construction.

Other notable projects still moving ahead in the United States include the 650-mile (1,046-km) Wink-to-Webster Pipeline, a joint venture between affiliates of Exxon Mobil, Plains All American and MPLX. The pipeline will transport 1 MMbpd crude oil and condensate from the Permian Basin to the Texas Gulf Coast upon expected completion in early 2021. Also, in the Permian Basin, Enterprise Products Partners’ 450,000-bpd Midland-to-Echo 3 crude oil pipeline is slated to begin service by September 2020. 

Enbridge is pursuing state regulatory approvals to replace the U.S. portion of its Line 3 replacement project after completing the Canadian portion of the 1960s-era pipeline earlier this year. The $2.9 billion U.S. stretch would extend from North Dakota across Minnesota and Wisconsin. Farther east, EQM is proceeding with construction of its 300-mile (482-km), 2-Bcfd (56-MMcm/d) Mountain Valley natural gas pipeline, although its targeted completion date has been pushed to early 2021 and its estimated cost rose another 5% this year to $5.7 billion. 

Whitewater Midstream, MPLX and partners secured funding in June to proceed with construction of Whistler Pipeline, a 500-mile (804-km) natural gas project scheduled to commence operation in the third quarter of 2021. The project will add 2 Bcfd of capacity from the Permian Basin to the Agua Dulce area of South Texas.

Energy Transfer continues to target 2020 completion of its Sunoco Mariner East expansion project, although work was temporarily suspended in late March by a state government order halting business activity due to the coronavirus. The expansion will add 250,000 bpd to the system. 

[For an update on Mexico activity, see Mexico’s Endless Pipeline Possibilities, Frequent Disappointments.] 


Oil remains the dominant fuel in Africa, but with nearly 500 Tcf (14 Tcm) of proven natural gas reserves, there is growing movement toward development of natural gas infrastructure primarily to expand its power generation capacity.

Abu Dhabi National Oil Company (ADNOC) said in June that a consortium of investors agreed to bring $10.1 billion in foreign direct investment for natural gas pipeline assets valued at $20.7 billion. Under the agreement, ADNOC will lease its interest in assets to ADNOC Gas Pipelines for 20 years in return for a volume-based tariff subject to a floor and a cap.

Nigeria National Petroleum Corporation (NNPC) started construction of the biggest natural gas pipeline in the country’s history – a $2.8 billion, 384-mile (614-km) project from Ajaokuta to Kano. The 40-inch (1,016-mm) line will transport 3.5 MMscf/d (98,882 cm/d) from multiple gathering projects in southern Nigeria, resulting in the establishment of a connecting network between its eastern, western and northern regions.

Tanzania and Kenya are constructing a 345-mile (558-km) gas pipeline between Tanzania’s Dar es Salaam and Tanga and on to Mombasa, in Kenya’s coastal city of Mombasa. The project, which is being developed under a contract by China Petroleum Technology and Development Corp., will meet the estimated gas demand of 50 MMscf/d (1 MMcm/d) in the two countries. Demand is projected to rise to 150 MMscf/d (4 MMcm/d) by 2035.

A group of 15 West African countries is studying the feasibility of extending the 420-mile (678-km) West African Gas Pipeline, owned by the JV West African Gas Pipeline Co. (Wapco). Launched in 2010, the pipeline connects the Escravos-Lagos pipeline at Nigeria Gas Co.’s Itoki export terminal to Takoradi in Ghana, with laterals to points in Ghana, Benin and Togo. 

A growing number of LNG projects also are under development in several areas of Africa, including the two-train, onshore LNG export terminal at Lindi in southern Tanzania. BG Group, ExxonMobil and Ophir Energy hope to overcome some land acquisition challenge to start construction this year.

In June, partners in the $20 billion, Total-led Mozambique LNG received a $2.25 billion government guarantee to pay the state oil company’s equity share of the project, if required. Scheduled to start in 2024, it is one of several LNG developments planned since the discovery of a massive gas field offshore Mozambique. A number of offshore pipeline projects also are in the planning stages.

A number of major African crude oil pipelines continue to languish, but there are signs of life. Construction began earlier this year in Niger’s Diffa region on a $7 billion China National Petroleum Corp. pipeline to deliver oil to the West African coast through neighboring Benin. The first phase of the 1,232-mile (1,982-km) project requires an investment of $4 billion through 2021, according to the Associated Press.

The first weld on the Power of Siberia. (Photo: Gazprom)


China continues to play a leading role in regional energy consumption and infrastructure construction, and there were high expectations for 2020 after it consolidated its midstream operations last year into a single, state-held company and opened access to foreign and private producers. 

Consensus forecasts call for gas demand to rise 4-6% in 2020, down from an estimated 10% growth rate in 2019, while LNG imports are projected to grow by 4% this year compared with earlier expectations of 12-14%. But economic recovery appears sluggish even in those areas where the virus is all but eradicated – a pattern repeated in other growth regions of Asia – and projections remain fluid.

China’s COVID-19 infections peaked early, and pipeline work on some major projects restarted as early as February, including the 690-mile (1,110-km) middle section of the China-Russia east-route natural gas pipeline. The middle section stretches from Changling County in the northeastern Jilin Province to Yongqing County in the northern Hebei Province, connecting with the north section that entered service last year. The middle section is scheduled for startup in late 2020.

India has emerged as a hotspot for natural gas pipeline construction in the region as it seeks to double the share of gas in its energy mix to 15% by 2030. To achieve this, companies are investing $60 billion in a network to expand LNG import facilities in the west and build pipelines connecting them to every state before the current government’s term ends in mid-2024, according to India’s energy minister. 

One major project already well underway by India’s biggest gas utility, Gail Ltd, is the 1,660-mile (2,660-km) Urja Ganga pipeline project, which will connect the eastern states of Bihar, West Bengal, Jharkhand and Odisha, with a capacity of 16 MMscf/d (452,034 MMcm/d) – an amount equal to roughly 10% of India’s total daily consumption. Gail hopes to bring the system online by the end of this year. 

A northeast gas grid is also under construction to connect eight states in northeastern India, a region bordering Bhutan, Myanmar, Bangladesh and China, with completion expected in 2023. Earlier this year, India approved funding for a $774 million (55.6 billion rupees) gas pipeline in the region. 

In addition to the gas buildout, Indian Oil, Bharat Petroleum and Hindustan Petroleum formed a consortium last year to construct the 1,700-mile (2,757-km) Kandla-Gorakhpur liquefied petroleum gas (LPG) pipeline. The project, scheduled for completion in 2024, will source LPG from west coast import terminals and supply bottling plants along the route. Indian Oil will expand the capacity of its Kandla LPG import terminal to feed the project.

The country also launched its first gas trading exchange in June, enabling local and foreign players such as Shell, Vitol and Trafigura to sell directly to domestic customers. 


Declining domestic production and increasing natural gas demand have made Europe a natural target for pipeline gas and LNG exporters, prompting an uptick in infrastructure construction in recent years. 

Gazprom has targeted Europe with major natural gas pipelines across the Baltic and Black Seas, including TurkStream, which is already flowing, and Nord Stream 2, which has only a short stretch of construction and some U.S. sanctions standing in the way of its completion [see Russia & CIS]. 

Concerns over Europe’s growing reliance on Russian gas has added motivation for some countries to build new infrastructure that diversifies their supply sources. Polish and Danish gas grid operators Gaz-System and Energinet are moving ahead with Baltic Pipe, a 528-mile (850-km) bidirectional project that gives Denmark, Poland and Sweden direct access to Norway’s North Sea gas and moves Poland closer to its goal of becoming eastern Europe’s gas hub. 

The project will deliver up to 353 Bcf (10 Bcm) per year upon expected completion in 2022 at a projected cost of $1.88 billion. Poland and Denmark are financing construction, along with a $243 million contribution from the European Commission. 

The Baltic Connector, which links Finland’s gas network with the Baltic states, just came online, providing a key piece of a planned system that will eventually make it possible for all Baltic states to import gas from Poland. The Gas Interconnection Poland–Lithuania (GIPL), a bidirectional gas pipeline linking the Baltic states with Poland, will add to the network in late 2021.

Bulgaria is scheduled to complete the bidirectional Greece-Bulgaria Gas Interconnector (ICGB) by the end of this year, ending its total dependence on Russian gas and helping to diversify supplies in southeastern Europe. The $268 million, 113-mile (182-km) link will have initial annual capacity of 105 Bcf (2.97 Bcm). Bulgaria Energy Holding (BEH) holds a 50% stake in the project, while Greece’s state energy firm (DEPA) and Italy’s Edison each hold 25%. 

ICGB will carry mainly Azeri gas via the Trans Adriatic Pipeline (TAP), which also is scheduled for completion by the end of 2020. The 710-Bcf (20-Bcm) per annum TAP will bring natural gas to Italy and onward to Adriatic countries, including Greece and Albania. Investors include BP, the Oil Company of Azerbaijan Republic and Snam, each with 20%, along with Fluxys (19%), Enagás (16%) and Axpo (5%). 

Middle East

The Middle East has continued to build out its natural gas infrastructure following large discoveries in the Eastern Mediterranean during the past decade and the growing availability of low-priced LNG. Some governments have also focused on the construction of new crude oil pipelines, although the pandemic has slowed progress of at least one major project.

The Iraqi oil ministry in December announced the completion of its pre-qualification process for construction of an estimated $18 billion oil pipeline that would carry 1 MMbpd of oil from Basra through the Jordanian port of Aqaba and across the Red Sea to Egypt. The first phase of the project would be constructed in Iraq across a 435-mile (700-km) stretch between Rumaila and Haditha. Developers delayed the May 2020 deadline for technical offers for the project, known as the Iraq Jordan Export Pipeline (IJEP), due to COVID-19. Energy ministers in both Jordan and Iraq have reiterated their support for the project but have yet to reschedule a meeting with interested bidders.

In neighboring Iran, President Hassan Rouhani launched a 620-mile (1,000-km) crude oil pipeline from Goreh to Jask in June, noting its strategic value as a secondary export route “whenever the Strait of Hormuz faces danger.” About 20 MMbpd of oil passes through the narrow strait, making it vulnerable to military blockades.

The United Arab Emirates’ Brooge Petroleum and Gas Investment Co. (BPGIC) recently announced plans to move ahead with the second phase of its oil storage expansion in Fujairah, adding eight more storage tanks with a combined capacity of 3.8 million barrels. The project is scheduled for completion by the end of this year.

A third phase would expand storage by an additional 22 million barrels, raising total capacity at the complex to 28 million barrels in late 2022. BPGIC signed an agreement in February with customer AI Brooge International Advisory to finalize studies for the construction of a 25,000-bpd refinery to start operations in the third quarter of 2021.

Bahrain became the 43rd country to import LNG after mechanical construction and commissioning of the first LNG import terminal in Bahrain was completed in March, according to owner Bahrain LNG WLL (BLNG). The floating storage unit (FSU) Bahrain Spirit is an onshore receiving facility at the Khalifa Bin Salman Port. Other infrastructure includes an adjacent regasification platform, subsea gas pipelines from the platform to shore and onshore gas receiving and nitrogen production facilities. Additional LNG import developments are in various planning stages for both UAE and Lebanon.

Construction work at a snowy Power of Siberia site. (Photo: Gazprom)

Russia & CIS

Russia’s growth strategy for natural gas pipeline exports has targeted Europe since the 1950s, but it is expanding its flow of gas to the east by targeting China’s growing energy demand.

Last year, state-owned giant Gazprom completed construction of the 1,865-mile (3,000-km), Power of Siberia pipeline, with capacity to transport 1.34 Tcf (38 Bcm) per year across Eastern Russia to China. This spring, Gazprom began a feasibility study for a Power of Siberia-2 project, which could deliver another 1.77 Tcf (50 Bcm) of gas per year across Mongolia to China. 

But Europe remains squarely in its sights, and Gazprom is determined to overcome U.S. sanctions that have so far prevented completion of its Nord Stream 2 pipeline across the Baltic Sea to Germany. Those sanctions forced All Seas to halt pipelaying in December with only 75 miles (120 km) remaining. In early July, Denmark gave permission to use pipelaying vessels with anchors to complete the final stretch of the pipeline in Danish waters, removing a key obstacle. The Russian pipelaying vessel Fortuna, which is potentially able to complete the Nord Stream 2, departed within two days of that decision from the German port of Mukran in the Baltic Sea. 

Its other major export pipeline project, TurkStream, began delivering natural gas via Turkey to Bulgaria in January. Bulgaria’s prime minister said in early June that the 295-mile (474-km) Balkan Stream extension will be ready by the end of 2020 despite construction delays due to the COVID-19 crisis. Balkan Stream will carry up to 706 Bcf (20 Bcm) per year of mainly Russian gas from TurkStream to Bulgaria, Serbia and Hungary.

Despite their cooperation on TurkStream, relations between Turkey and Russia have been patchy in recent years, and that – along with depressed LNG prices – may have encouraged Turkey to deliberately prolong a recent maintenance outage on the Blue Stream pipeline. Blue Stream was supposed to resume deliveries in May, but Reuters sources say Ankara has been replacing Russian supplies with lower-priced U.S. LNG and dry gas via the Trans-Anatolian pipeline from Azerbaijan.

South & Central America

Proven reserves of natural gas in South and Central America represent only a tiny fraction of global reserves, but pipeline infrastructure in the region is insufficient to meet growing demand.

Brazil’s state energy research office EPE said last September that its growth projections justify construction of 16 new pipelines, although their status is uncertain as the country faces one of the world’s most severe coronavirus outbreaks. Among the recommended pipelines, five would be offshore; among others, the largest would be a 563-mile (906-km) project connecting Sao Carlos to the capital city, Brasilia. Further east, the state of Bahia has already begun construction on the final section
of the 190-mile, $100 million Southwest Gas pipeline.

In El Salvador, Energia del Pacifico (EDP) is constructing an LNG-to-power project at the Port of Acajutla scheduled for completion by the end of 2021. The project is comprised of a 378-MW natural gas-fired power plant, a floating storage regasification unit (FSRU), and a 27-mile (44-km) electric transmission line that will connect to the Central American Electrical Interconnection System, strengthening the country’s electric grid. EDP said the project drew about $1 billion in foreign direct investment, describing it as the single-largest private investment in El Salvador’s history.

Oil transportation companies in Colombia this summer agreed to extend reductions for pipeline charges due to the impact of the COVID-19 pandemic on prices and demand, according to the Cenit subsidiary of state-run Ecopetrol. At the end of April, Cenit said it would offer financing to reduce pipeline tariffs by 50% for two months.

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