Offshore Pipeline in Brazil Gets Early Approval
Brazil’s Energy Research Company (EPE) has greenlit a key technical step for a proposed offshore pipeline project led by Equinor, aimed at transporting natural gas from the Raia fields in the pre-salt region of the Campos Basin to the national grid, according to Brazil Energy Insight.
The EPE’s approval clears the way for early-stage construction and installation work to begin.
According to EPE, the project aligns with Brazil’s strategic energy goals, particularly its Gas for Employment Program, which seeks to tap domestic gas resources to lower energy costs and strengthen infrastructure.
EPE President Thiago Prado emphasized that the evaluation process upheld technical rigor and met all deadlines, adding that this move demonstrates how energy planning can drive investment and infrastructure security.
The gas pipeline will span a total of 127 miles (204 km), primarily offshore, linking production units near the Raia Manta and Raia Pintada fields, located roughly 124 miles (200 km) off the coast of Rio de Janeiro, to Macaé in the state of Rio de Janeiro.
The pipeline system includes an offshore connection to a floating production, storage and offloading unit (FPSO), which will feed gas to the seabed pipeline. The offshore portion will reach depths of about 2,700 meters and will be protected by burial in shallow areas. It will make landfall at Praia do Lagomar using HDD and continue onshore for 2.4 miles (4 km) via a corridor already used by other pipelines.
Onshore, the pipeline will link to the Gas Receiving Station (ERG), where it will connect to Nova Transportadora do Sudeste’s (NTS) pipeline network. The pipeline route will cross two highways and run near protected areas and residential neighborhoods. It will also feature a PIG system (Pipeline Inspection Gauge) for internal maintenance and monitoring.
The Raia project is operated by Equinor (35%) with partners Repsol Sinopec (35%) and Petrobras (30%). It comprises three significant pre-salt finds, Pão de Açúcar, Gávea, and Seat, with combined recoverable resources estimated above 1 Bboe. Once operational in 2028, the pipeline could deliver up to 16 MMcm/d of natural gas, enough to cover 15% of Brazil’s domestic demand.
Enbridge Plans 86-Mile Expansion in B.C.
Enbridge’s proposed Sunrise Expansion project could bring up to 850 workers to the Mackenzie region in British Columbia as the company moves forward with plans to boost capacity along its Westcoast natural gas pipeline, according to the Prince George Citizen.
Representatives from Enbridge shared project details with the Regional District of Fraser-Fort George on June 19, noting the buildout would include 86 miles (139 km) of new pipeline looping and several compressor station upgrades along the T-South section of the system, according to the Prince George Citizen.
The expansion spans from the Pine Pass area to the U.S. border at Huntington-Sumas.
The Westcoast pipeline, which stretches nearly1,802 miles (2,900 km) from Fort Nelson to southern B.C., plays a key role in regional gas transmission. Originally constructed in 1957, it is now operated by Enbridge following a series of ownership changes.
Looping work within the Fraser-Fort George district includes six pipeline segments ranging in length from 3.1 to 13 miles (5 to 21 km), as well as a new gas-powered compressor unit near Azouzetta Lake. Additional electrified compressor stations are planned at 93 Mile House, Kingsvale and Othello, supported by (10 km) of new power lines.
To accommodate construction crews, Enbridge plans to set up two temporary workforce camps: one near Mackenzie for up to 700 workers and another near Powder King for 150.
The Sunrise project application was submitted to the Canada Energy Regulator in May 2024 and deemed complete last fall. The regulatory review is expected to conclude in 2026, with the new infrastructure targeted to come online by the end of 2028.
Cheniere GreenLights Corpus Christi LNG Expansion
Cheniere Energy’s approved the final investment decision for the expansion of the Corpus Christi LNG project and added that Bechtel Energy has requested permission to move forward the related construction, CCL Midscale Trains 8 and 9.
Separately, the company said it has been developing further brownfield liquefaction capacity expansions at both the Corpus Christi and Sabine Pass terminals.
Cheniere wants to double its current LNG production to 90 mtpa by building more export facilities at Sabine Pass and Corpus Christi.
The LNG exporter will start construction with single-train expansions at each site, which would increase its LNG platform up to 75 mtpa in the early 2030s.
Cheniere expects use more than $25 billion of available cash through 2030 toward growth, share repurchases, balance sheet management and dividends.
Bilfinger to Upgrade UK Gas Pipeline Controls
Bilfinger UK landed a multimillion-dollar contract from National Gas to upgrade control systems that keep natural gas moving through Britain’s National Transmission System (NTS).
The work centers on the Felindre Compressor Station in South Wales and is expected to create up to 100 jobs.
Compressor stations positioned along the NTS use multiple units to pressurize gas, helping it travel at speeds of roughly 25 mph (40 km/h). Bilfinger will serve as both principal designer and principal contractor on the project, funded under Ofgem’s Control System Refurbishment Program.
The three-year assignment follows two years of front-end engineering design and adopts a two-stage, early-contractor-involvement model. A core team in Warrington will lead design and panel fabrication, supported by Bilfinger personnel in Chesterfield, St. Helens and on site. Staffing will peak at about 100 during construction, with 40-50 people engaged in design.
Freeport LNG Seeks 40-Month Extension on Expansion
Freeport LNG requested a 40-month extension from federal regulators to complete the long-delayed Train 4 liquefaction unit at its Texas export terminal, citing setbacks from a 2022 explosion and the subsequent years-long recovery process.
In a letter filed June 18 with the Federal Energy Regulatory Commission (FERC), Freeport asked to move its in-service deadline from August 1, 2028, to December 1, 2031, stating it needs more time to finalize financing and resume construction.
The proposed Train 4 would add additional liquefaction and pretreatment capacity to Freeport’s existing LNG export facility on Quintana Island in Brazoria County.
The developer emphasized that restoring full operations after the 2022 incident took precedence over advancing Train 4, but with the terminal now fully operational as of May 21, it is refocusing efforts on commercializing the expansion.
“Certainty regarding Freeport’s ability to complete project construction by the in-service deadline is essential to commercialization of the project,” the company said in the filing, adding that it has spent $111 million to date on Train 4 development and has retained an EPC contract with Kiewit Energy Group.
Freeport said the 48 to 56 months required to build the facility, paired with ongoing market engagement, make it impossible to meet the current schedule. It noted longer procurement lead times for equipment and materials are also contributing to delays.
No modifications to the originally authorized project are proposed.
Argentina Restores Gas Flow Following Demand Strains
Argentina reinstated normal shipping of natural gas, ending supply restrictions on industries after cold weather caused record domestic demand, the country’s energy secretariat said.
The record freezing cold, forced Argentina, home to the Vaca Muerta shale formation, to suspend its emerging gas exports to provide for local communities.
Restrictions, which had been imposed on industries and compressed natural gas (GNC) stations due to record residential demand from the coldest weather in 30 years, were in effect for from July 2 through July 4.
“The gas transportation system is no longer in emergency and pressures in gas pipelines and stations for its regulation and measurement have been normalized,” the secretariat said in a statement.
North Baja Expansion Boosts Mexico LNG Hopes
TC Energy’s North Baja Xpress expansion received regulatory clearance from the Federal Energy Regulatory Commission (FERC), advancing Mexico’s pathway to becoming an LNG exporter.
The approval, granted May 31, allows TC Energy to begin service on upgrades to the Ehrenberg compressor station in La Paz County, Arizona, which will increase southbound pipeline capacity to the U.S.-Mexico border by 495 MMcf/d.
The pipeline, which runs 80 miles through Arizona and California to the Mexico border, is a key part of the supply chain feeding Sempra Energy’s (SRE) Energia Costa Azul LNG facility on Mexico’s Pacific coast. The expansion of Costa Azul, which is converting the terminal from import to export capability, is expected to come online before the third quarter is over.
The bi-directional pipeline can move up to 600 MMcf/d northbound and 500 MMcf/d southbound, with current flows averaging around 380 MMcf/d into Mexico. East Daley estimates the expansion will enable the line to deliver up to 430 MMcf/d to Costa Azul once liquefaction operations begin. P&GJ