COMPRESSORtech2 - July 2025

Compression offers custom-engineered components, repair and reconditioning services and technical support for reciprocating compressors around the world. Our solutions extend run times, increase efficiency, address emissions, reduce operating

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EDITORIAL

Editor Jack Burke

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Vice President of Content, Power

Becky Schultz

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PRODUCTION

Client Success & Delivery Manager

Charlotte Kemp

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Group Design Manager Jeff Gilbert

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CIRCULATION

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SALES

Brand Manager

PLUS mainland Europe

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China

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Italy

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Japan

Michihiro Kawahara

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Scandinavia/UK/Benelux

Greg Roberts

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USA

Kristin Pride

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Vice President Sales, Power Division

Tony Radke

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Global Vice President Sales

Alister Williams

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Chief Executive Officer

James King

Chief Financial Officer

Paul Baker

Chief Operating Officer

LNG by the numbers

The International Energy Agency’s (IEA) online Global LNG Capacity Tracker provides more than just a dashboard of FIDs for new export projects for market watchers—it offers evidence that long-term investor confidence in LNG is not only intact, but rising. Despite recent headlines about market oversupply, cost inflation, and environmental pressures, the scale of LNG projects moving forward suggests the market is betting big on gas for decades to come.

Between 2025 and 2030, nearly 290 billion cubic meters per year (bcm/yr) of new LNG export capacity is expected to come online from projects that have already reached final investment decision (FID) or are under construction. This is not a speculative forecast—it’s a concrete, already-funded buildout representing the largest wave of LNG capacity additions in history. When companies are committing billions of dollars to liquefaction projects that won’t begin full-scale operation for another four or five years, it speaks volumes.

This is not just about momentum or sunk cost. From 2019 through mid-2025, more than 335 bcm/yr of capacity reached FID—more than double the rate of approvals during the 2014–2018 period. After a brief dip in 2020 due to the COVID-19 pandemic, LNG development rebounded sharply. The reasons are clear: global energy security concerns, persistent demand growth in Asia, and Europe’s pivot away from Russian pipeline gas have all elevated LNG as a core pillar of energy diversification strategies.

The United States has emerged as the undisputed leader in this expansion wave. U.S. projects account for nearly half of all post-2019 FIDs, driven by their cost competitiveness, speed to market, and contractual flexibility. Even after a pause in new approvals during 2024, U.S. developers came roaring back in 2025 with Louisiana LNG and CP2 LNG both moving forward. This rapid rebound suggests developers are confident not just in future demand, but in the regulatory environment and financing conditions needed to deliver on that demand.

Critics may point to risks—cost overruns, project delays, or the possibility of future oversupply—but these are longstanding features of LNG markets. What has changed is the breadth of buyer interest and the global rebalancing of supply chains. In 2022–2023, North America dominated new LNG FIDs; in 2024, it was the Middle East. Now in 2025, the U.S. is once again the epicenter of LNG investment. That geographic dynamism reflects a broader truth: LNG is no longer a niche business for a few producers, but a competitive global industry.

The core trend is unmistakable: capital is flowing into LNG infrastructure at a pace we haven’t seen before.

KHL GROUP AMERICAS LLC

Trevor Pease Jack Burke

14269 N 87th Street, Suite 205, Scottsdale, AZ 85260. americas@khl.com

If money talks, then the message is clear. Global investors and developers are signaling their belief that LNG will be a vital, in-demand energy source well into the 2030s and beyond. And for a fuel often labeled as transitional, that’s a very long runway.

| jack.burke@khl.com

VOLUME 30 | NUMBER 6

COMPRESSORTECH2 ISSN 1085-2468, is published monthly with combined issues of January/ February and August/September by KHL Group Americas LLC, 14269 N 87th, Suite 205, Scottsdale, Arizona, 85260, USA. Periodicals postage is paid at Scottsdale, AZ, and additional mailing offices (if applicable).

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PARTNERS IN TRAINING

24 Kodiak invests in hands-on training

TECHNOLOGY

28 Neuman & Esser’s latest storage project

30 Special report on Europe’s hydrogen infrastructure

36 Advanced flame detection technology

DEPARTMENTS

3 Editor’s Comment: LNG projects booming

6 Industry News: Baker Hughes’ big order

8 Gas Lines: U.S. electricity demand to surge

12 Company News: Woodfibre LNG hits milestone

14 Monitoring Government: Williams Co. tries to revive stalled pipelines

17 Shale Play by Play: Gulfport signals interest in mergers, acquisitions

20 Euro Gas Report: SEFE signs 10-year gas import deal

Subscribe now: Scan this code to receive all the latest news in the

38 Tech Corner: Turbomachinery keys

41 Cornerstones of Compression: Evolution of pipelines, compressor stations

Baker Hughes wins power contract for data centers

Baker Hughes has secured a major equipment award from Frontier Infrastructure Holdings, a portfolio company of Tailwater Capital LLC, for its NovaLT gas turbines to power large-scale data center projects in Wyoming and Texas.

Under the agreement, Baker Hughes will deliver 16 NovaLT gas turbines and

Honeywell expands energy transition portfolio

Honeywell has agreed to acquire Johnson Matthey’s Catalyst Technologies business in a strategic move that significantly strengthens its position in energy transition technologies. The all-cash transaction, valued at £1.8 billion, will integrate the UK-based catalyst and process technology provider into Honeywell’s Energy and Sustainability Solutions (ESS) segment.

The deal enhances Honeywell’s ability to serve the refining and petrochemical markets while enabling it, for the first time, to deliver a comprehensive suite of technologies for producing low-emission fuels. These include sustainable methanol, sustainable aviation fuel (SAF), blue hydrogen, and blue ammonia — all central to energy security and decarbonization strategies worldwide.

“The acquisition of Johnson Matthey’s Catalyst Technologies business broadens Honeywell’s role as a world-class technology provider of critical energy needed to drive growth into the future,” said Vimal Kapur, Chairman and CEO of Honeywell. “As demand for diversified sources of energy continues accelerating, we will better enable Honeywell to offer the innovation our customers need.”

THE U.S. DEPARTMENT OF ENERGY (DOE) concluded that U.S. liquefied natural gas (LNG) exports are not inconsistent with the public interest, despite extensive debate over environmental, economic, and geopolitical implications. The finding comes in response to more than 100,000 public comments submitted following the release of the agency’s 2024 LNG Export Study in December.

The DOE’s Response to Comments aims to clarify

and address concerns raised during the public comment period and will guide future adjudications of LNG export applications to non-free trade agreement (non-FTA) countries.

One of the study’s central themes is the role of market forces in determining the actual volume of LNG exports. DOE stated that while the U.S. has authorized exports exceeding projected demand under most scenarios, authorization does not guarantee project success. Factors

associated equipment—gears and Brush Power Generation four-pole generators— to support dedicated energy islands at Frontier’s behind-the-meter power generation sites. The turbines will provide up to 270 MW of power.

The award builds on a strategic agreement signed in March 2025 between Baker Hughes and Frontier to accelerate deployment of carbon capture and storage (CCS) and power solutions across the United States, including the Sweetwater Carbon Storage Hub in Wyoming.

“This award underscores our commitment to advancing sustainable energy development through reliable and efficient power solutions that cater to the diverse needs of the industry,” said Ganesh Ramaswamy, executive vice president of Industrial & Energy Technology at Baker Hughes. “Leveraging our comprehensive range of integrated power solutions for Frontier’s U.S. data center projects demonstrates innovative, scalable and lower-carbon technologies helping to meet the growing demand for power.”

The NovaLT gas turbine is a multi-fuel solution that can start up and run on different fuels, including natural gas and 100% hydrogen. CT2

such as global energy trends, infrastructure development, and regional demand — especially from Asia and Europe — will ultimately determine export volumes.

TOTALENERGIES has signed a long-term agreement to purchase 2 million metric tons per annum (Mtpa) of LNG from the proposed Ksi Lisims LNG project in British Columbia, Canada. The 20-year Sales and Purchase Agreement (SPA) is subject to a final investment decision on the project.

In addition to the offtake agreement,

A NovaLT 16 gas turbine. Baker Hughes will supply 16 NovaLT turbines to Frontier Infrastructure.

NRG Energy to acquire LS Power gas generation

In a move that significantly expands its generation portfolio, NRG Energy has announced it will acquire 13 GW of natural gas-fired power plants and a leading commercial and industrial virtual power plant (C&I VPP) platform from LS Power in a cash and stock deal valued at $12 billion enterprise value.

The acquisition, expected to close in the first quarter of 2026, doubles NRG’s total generation capacity to 25 GW, with the new assets concentrated in Texas and the Northeast—two regions where NRG already serves a large retail load. The deal positions NRG to capitalize on growing U.S. energy demand and ongoing tightening of power market supplydemand balances.

The 18 natural gas-fired facilities included in the deal are modern, quick-start units that strengthen NRG’s operational flexibility, simplify risk management, and reduce cost-to-serve. Many of the assets were expanded and redeveloped by LS Power, which will retain ownership of approximately 10 GW of generation assets, including natural gas, renewables, and storage.

TotalEnergies has acquired a 5% equity stake in Western LNG, the project developer, and future operator of the facility. The deal includes an option for TotalEnergies to expand its interest in Western LNG and/ or take a direct ownership stake in the liquefaction plant—potentially up to 10%— once the project reaches a final investment decision.

Ksi Lisims LNG is a proposed 12 Mtpa liquefaction facility on the Pacific coast of Canada, offering direct access to key Asian LNG markets.

Enbridge said its Westcoast system has been the backbone of British Columbia’s natural gas industry since 1957.

First Nations acquiring stake in gas pipeline

A coalition of 36 First Nations in British Columbia will acquire a 12.5% ownership stake in Enbridge Inc.’s Westcoast natural gas pipeline system through a CAD$715 million transaction. The agreement marks one of the largest Indigenous equity investments in Canadian energy infrastructure to date.

The Westcoast system, owned by Westcoast Energy Inc., a wholly owned subsidiary of Enbridge, stretches more than 2,900 km from Fort Nelson in northeastern B.C. and from Gordondale near the B.C.Alberta border, to the Canada–U.S. border at Huntingdon/Sumas. It transports up to 3.6 billion cubic feet per day of natural gas to

Dr. Dominik Schollenberger,

SIEMENS and TURN2X have announced a strategic partnership aimed at accelerating the production of renewable natural gas

customers across B.C., Alberta, and the U.S. Pacific Northwest.

The investment is being led by the Stonlasec8 Indigenous Alliance Limited Partnership (Stonlasec8), representing First Nations communities along the pipeline corridor. To support the deal, the Canada Indigenous Loan Guarantee Corporation (CILGC), a subsidiary of Canada Development Investment Corporation (CDEV), has committed a CAD$400 million loan guarantee.

The transaction is expected to close by the end of the second quarter of 2025, subject to completion of required financing and other conditions. CT2

(RNG). Under the agreement, Siemens will become a preferred technology provider and supplier for TURN2X’s green methane facilities, delivering advanced automation, digitalization, and energy management tools to help scale operations. Germany-based TURN2X produces climate-neutral methane by synthesizing green hydrogen with carbon dioxide captured from bioethanol plants. The resulting RNG is fully compatible with existing natural gas infrastructure, including pipelines and storage.

IMAGE: ENBRIDGE

Co-Founder and CTO of TURN2X (l.) and Axel Lorenz, CEO of Process Automation Siemens.

U.S. electricity demand jumping

U.S. electricity consumption is projected to rise in 2025 and 2026, surpassing the record set in 2024, according to the latest Short-Term Energy Outlook from the U.S. Energy Information Administration (EIA).

The increase marks a notable shift from nearly two decades of flat demand. Between the mid-2000s and early 2020s, electricity use held steady as efficiency gains and economic changes offset population and economic growth. During that period, structural shifts – such as the move from manufacturing to less energy-intensive service sectors – also contributed to stagnant demand.

The latest EIA outlook shows that demand has rebounded since a relative low in 2020. Total electricity use is expected to grow at an average rate of 1.7% annually through 2026. Consumption in the commercial sector, which includes energyhungry data centers, is forecast to grow by 2.6% per year, while the industrial sector, including manufacturers, will grow at a 2.1%

annual rate. Residential demand is expected to increase more modestly, averaging 0.7% growth annually – largely driven by weather patterns.

To meet the rising demand, electricity providers are expanding generating capacity, particularly in solar and battery storage. Much of the new capacity is being built in Texas, California, the upper Midwest, and the Northeast.

The surge in electricity use has also prompted broader efforts to reinforce grid reliability and efficiency. Utilities and grid operators are investing in high-voltage transmission lines, energy efficiency programs, and demand response strategies. These initiatives are backed by regulatory oversight and utility spending data analyzed by the Federal Energy Regulatory Commission. CT2

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Roth Hydraulics invests in honing capabilities

Roth Hydraulics GmbH has significantly increased its in-house machining capabilities with a major upgrade to its honing equipment, a move the company said will benefit manufacturers of large gas compression systems and other special hydraulic applications.

By doubling the maximum workpiece length its honing machine can accommodate—from 5 meters to 10 meters—Roth can now internally machine cylinder tubes up to 560 millimeters in diameter. The investment represents a

key advance in the company’s vertical integration strategy, giving it tighter control over a critical quality factor in piston accumulator production.

Piston accumulators are widely used in natural gas systems to maintain pressure, absorb shocks, and store energy. The integrity of their inner surfaces plays a critical role in system reliability and longevity. By bringing the honing of long cylinder tubes entirely in-house, Germany’s Roth has eliminated a key dependency on outside suppliers. The company said that

With the extension of the honing machine to a workpiece length of ten metres, Roth Hydraulics offers significant added value for large cylinder production.

outsourcing this work in the past led to long cycle times and higher transport costs. The internalization of the honing process also aligns with Roth’s broader environmental goals by reducing transportation-related emissions.

Woodfibre LNG hits major construction milestone

The Woodfibre LNG project reached a significant construction milestone, marking the arrival of its first large-scale modular components at the project site near Squamish, British Columbia. Seven

COOPER has appointed Edward Bonham as its new Technical Manager, reinforcing the company’s commitment to technical excellence in natural gas compression and midstream services.

specialized pipe rack modules were safely delivered via heavy cargo vessel and are now being prepared for offloading at the project’s newly completed Marine Offloading Facility.

“This is a huge milestone for the Woodfibre LNG project as it’s the start of our facility going vertical—where people will really start to see the facility take shape,” said Luke Schauerte, CEO of Woodfibre LNG. “These first modules are a significant step forward in diversifying Canada’s energy export market, providing global customers with responsibly produced energy and

Bonham joins Cooper with more than three decades of experience in operations, project engineering, and project management across the midstream gas sector. Over his career, he has held key positions at several

leading industry organizations, including Consolidated Natural Gas, Columbia Gas, DresserRand Company, Universal Plant Services Midstream, and Kinley Advanced Technical Services (KATS).

TECHNIP ENERGIES has appointed Marco Tiziano Barone as chief legal officer and member of its group executive committee, reinforcing the company’s leadership team as it

ensuring Canadians receive maximum benefit for their resources.”

This initial delivery represents the first seven of 19 modular components that will arrive at the site throughout the remainder of 2025 and into 2026.

These prefabricated modules vary significantly in scale—from a 126-tonne pipe rack to an 11,000-tonne liquefaction unit that will occupy roughly the same area as a football field.

Once complete, the Woodfibre LNG facility will produce 2.1 million tonnes of LNG annually for export to international markets.

continues to expand in LNG and hydrogen markets.

Barone brings nearly two decades of international legal, contracts, and compliance experience, including 12 years at Technip Energies. He succeeds Michael McGuinty, who is retiring.

Technip Energies is a leading engineering and technology company with a strong presence in LNG and hydrogen. The company reported €6.9 billion in revenues for 2024 and operates in 34 countries.

Woodfibre LNG hits major milestone as seven pipe rack modules arrive. IMAGE: WOODFIBRE LNG

PHOTO: ROTH HYDRAULICS

Höegh Evi signs FSRU charter with EGAS, supporting Egypt’s role as energy hub in the Middle East. IMAGE: HÖEGH EVI

Höegh Evi signs 10-year FSRU deal with Egypt’s EGAS

Marine energy infrastructure firm

Höegh Evi has signed a 10-year charter agreement with the Egyptian Natural Gas Holding Co. (EGAS) to deploy the floating storage and regasification unit (FSRU) Hoegh Gandria in Egypt starting in the fourth quarter of 2026.

Under the agreement, Hoegh Gandria will operate at the Port of Sumed, supplying up to 1 billion standard cubic feet per day (mmscf/d) of peak regasification capacity.

Höegh Evi will begin converting the Hoegh Gandria—originally an LNG carrier— into an FSRU immediately to meet the project timeline.

Hoegh Gandria will replace the Hoegh Galleon, which was temporarily deployed to Egypt in July 2024.

Neuman & Esser to supply compressors

Energy service provider EWE has awarded compressor manufacturer Neuman & Esser (NEA) a key technology contract for one of Germany’s largest electrolyzer facilities, a 320-megawatt green hydrogen plant under development in Emden. The project, a centerpiece of the broader “Clean Hydrogen Coastline” initiative, is scheduled to begin producing green hydrogen at industrial scale in 2027.

NEA will supply three dry-running, horizontal, 8-crank, 5-stage compressors— classified as size 320—for the project. The compressors are a critical part of the hydrogen production system, enabling efficient downstream processing and integration into storage and transportation networks.

The Emden hydrogen plant is the central component of Clean Hydrogen Coastline, a four-part project aiming to establish an end-to-end hydrogen value chain in northern Germany. The initiative covers hydrogen production, storage, transport and utilization, and received funding approval in 2024 through the European IPCEI (Important Project of Common European Interest) program.

EWE is currently finalizing detailed engineering and preparing the site for construction. Deep foundation work is

BAKER HUGHES has agreed to sell its Precision Sensors & Instrumentation (PSI) business to CRANE COMPANY for approximately $1.15 billion in cash, a move that advances Baker Hughes’ effort to streamline its portfolio and focus on core industrial and energy technologies. The transaction, announced June 9, includes globally recognized brands Druck, Panametrics and Reuter-Stokes.

The PSI division, part of Baker Hughes’ Industrial & Energy Technology (IET) segment, specializes in advanced

expected to begin in winter 2025, followed by structural work and installation of electrolysis equipment. Once operational, the facility will use renewable electricity— primarily wind power—to produce hydrogen, reinforcing regional energy security and supporting Germany’s broader decarbonization strategy.

This marks the second hydrogen-related compressor contract EWE has awarded to Neuman & Esser. In March 2025, EWE selected NEA to supply compressor technology for a hydrogen storage project in Huntorf, Wesermarsch. The latest award reflects EWE’s confidence in NEA’s engineering capabilities and the companies’ shared commitment to advancing the hydrogen economy. CT2

the Clean Hydrogen Coastline initiative, a four-part project in northern Germany.

instrumentation used in pressure, flow, gas, moisture, and radiation measurement. The sale covers the entire business, including intellectual property.

EBARA ELLIOTT ENERGY (EEE) has signed a purchase agreement for the installation of a High-Speed Balancing Bunker (HSB) in Saudia Arabia, expanding its turbomachinery service capabilities and its long-term commitment to the Middle East. The HSB, expected to begin operations in 2027, will be integrated into EEE’s operations in the Kingdom.

EWE has selected Neuman & Esser technology for the Emden electrolyzer, part of

IMAGE:

EWE

Trump administration may help resuscitate Northeast U.S. natural gas pipeline projects

Encouraged by the Trump administration, Williams Companies may breathe new life into two natural gas pipeline projects in the northeast United States. By Brian Ford

Williams’ Constitution and Northeast Supply Enhancement (NESE) projects had been shelved after years of encountering strong resistance from state officials and various environmental interest groups.

The 124-mile, 30-inch diameter Constitution Pipeline would move 650 million cubic feet per day from Susquehanna County, Pennsylvania, to Schoharie County, New York, supplying natural gas from the Marcellus Shale to New York markets. The 37-mile NESE project, a 400 million-cubic-foot-per-day expansion of the Transcontinental Gas Pipeline in New York, New Jersey and Pennsylvania, would transport gas to the New York and New Jersey markets.

The company cancelled the Constitution Pipeline in 2020 after a fight with the then New York Gov. Andrew Cuomo. “The underlying risk adjusted return for this greenfield pipeline project has diminished in such a way that further development is no longer supported,” the company wrote in its announcement.

Williams pulled the plug on the NESE project in 2024 after failing to get permits in both New York and New Jersey. Both projects had been denied Clean

Water Act water quality certifications.

But after achieving his second term in office, President Donald Trump voiced support for reviving the Constitution project.

“We are going to get this done, and once we start construction, we’re looking at anywhere from nine to 12 months, if you can believe it,” Trump told reporters in February.

Of Windfarms and Pipelines

In an unusual turn of events, the outlook for the Constitution pipeline seemed to improve as a result of negotiations over an offshore windfarm project.

In his drive for U.S. fossil fuel energy dominance, Trump has made it clear he is no fan of offshore wind power, placing a moratorium on new and renewed leases of the U.S. Outer Continental Shelf for wind power and telling the heads of various agencies to “not issue new or renewed approvals, rights of way, permits, leases, or loans for onshore or offshore wind projects pending the completion of a comprehensive assessment and review of Federal wind leasing and permitting practices.”

On April 16, U.S. Interior Secretary Doug Burgum issued a stop-work order on the Empire Wind project by Norway’s Equinor off the coast of New York, saying on the social media platform X that he ordered the Bureau of Ocean Energy Management (BOEM) “to immediately halt all construction activities on the Empire Wind project until further review of information that suggests the Biden administration rushed through its approval without sufficient analysis.”

The halt of the windfarm project prompted New York Governor Kathy Hochul

to help mediate the issue with the Trump administration. Those talks resulted in the stop-work order on the US$5 billion windfarm project being lifted in May.

Also, while not being specific, Hochul said in a statement that she would “work with the administration and private entities on new energy projects that meet the legal requirements under New York law.”

In a post on X, Burgum wrote, “Americans who live in New York and New England would see significant economic benefits and lower utility costs from increased access to reliable, affordable, clean American natural gas.”

At this point, it might be more advantageous for Williams to revive the NESE project than the Constitution Pipeline.

When asked about the status of the Constitution Pipeline during the company’s first-quarter earnings conference call on May 7, outgoing Chief Executive Officer Alan Armstrong said, ”We certainly are working that project. Lots of hurdles to overcome there...it does require a combination of pipeline solutions to get all the way into the end markets up there...also working NESE, and excited about NESE. And, NESE’s a lot easier to pull the trigger on, frankly, just a lot less complex and highly dependent on the state of New York and the governor there deciding that they need low-cost, low-emission energy into those markets. So, we’ll see what happens on that.”

Reuters reported that the company has asked the Federal Energy Regulatory Commission (FERC) to reinstate a certificate of public convenience and necessity for the NESE project. CT2

BRIAN FORD is editor in chief for Industrial Info Resources, which provides up-to-date project information on a wide range of industries across the globe. He has worked as a reporter and editor for newspapers and other publications since 1979.

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TXO to acquire White Rock assets for $350 million

TXO Partners LP has agreed to acquire producing assets in the Elm Coulee field in the Williston Basin from White Rock Energy, a portfolio company of Quantum Capital Group, for approximately $350 million in cash. North Hudson Resource Partners LP, a TXO affiliate, will acquire a 30% nonoperated interest in the assets. Combined, the transaction is valued at $475 million. Following the acquisition, TXO will hold 190,000 acres in the Elm Coulee area of Montana and North Dakota.

BLM to fast-track Montana pipeline review

The Bureau of Land Management will conduct an accelerated environmental review of the Helena to Three Forks natural gas pipeline in Montana. The 74-mile, 16-inch buried pipeline would increase gas capacity in western Montana. If approved, construction is scheduled in phases between spring 2026 and fall 2029.

Continental testing new Williston formations

Continental Resources is testing new formations in the Williston Basin, company executives said at Hart Energy’s SUPER DUG 2025 Conference & Expo. CEO Doug Lawler declined to name the formations but said they resemble the geology of the Powder River Basin. Founder Harold Hamm also withheld specifics but confirmed the company is actively evaluating multiple targets in the region.

MARCELLUS/UTICA

Gulfport signals M&A interest

Four years after emerging from bankruptcy, Gulfport Energy is shifting from a potential acquisition target to a potential buyer. In its latest quarterly update, CEO John Reinhart said the company is actively evaluating opportunities to expand its leasehold footprint in Ohio’s Utica Shale.

“We continue to assess the landscape and remain optimistic about the opportunities to meaningfully increase our leasehold footprint to enhance resource depth,” Reinhart said during an earnings call. He added that Gulfport’s deal team is “currently assessing” properties across Ohio.

EOG to acquire Encino for $5.6 billion

EOG Resources Inc. will acquire Encino Acquisition Partners from Encino Energy and majority owner Canada Pension Plan Investment Board for $5.6 billion, including assumed debt. EOG will fund the deal with

James Willis highlights the latest news from the major North American shale plays

$3.5 billion in debt and $2.1 billion in cash. Encino became the top crude producer in the Utica after acquiring Chesapeake Energy’s Ohio assets in 2018. EOG already holds 460,000 acres in the play. The acquisition will add 675,000 net core acres, making EOG the largest leaseholder in the Ohio Utica with 1.1 million acres. The deal is expected to close in the second half of 2025.

Expand Energy drills longest onshore lateral

Expand Energy, formed from the merger of Chesapeake Energy and Southwestern Energy, drilled the longest onshore well and lateral in the U.S. to date. The BW Edge MSH 210H in Marshall County, West Virginia, features a 27,657-foot lateral and a total depth of 34,507 feet.

Report: Trump trades offshore wind for gas pipelines

Multiple media outlets report that President Trump struck a deal with New York Gov. Kathy Hochul allowing two previously blocked gas

PERMIAN

Riley Permian to acquire Silverback assets for $142 million

Riley Permian has agreed to acquire Silverback Exploration II LLC and its subsidiaries for $142 million. The assets include 47,000 net acres in Eddy County, New Mexico, adjacent to Riley’s existing position. Approximately 19,000 acres are prospective for the Yeso trend, with more than 300 gross undeveloped locations. Current production is 5,000 boe/d, with a 52% oil and 75% liquids mix. The deal is expected to close in early Q3 2025.

Permian Resources adds 13,000 acres in New Mexico

Permian Resources is acquiring 13,320 net acres and 8,700 net royalty acres from APA Corp., along with 12,000 boe/d of production, for $608 million. The acreage is more than 65% operated and located in Eddy County, New Mexico. Permian Resources has identified more than 100 gross two-mile operated locations with an average breakeven of $30 per barrel WTI. The deal is expected to close by the end of Q2 2025.

Targa’s Pembrook II plant on track for Q3 startup

Targa Resources Corp. reports construction is progressing on its 275 MMcf/d Pembrook II, East Pembrook and East Driver plants in the Permian Midland, as well as its 275 MMcf/d Bull Moose II and Falcon II plants in the Delaware Basin. In its logistics segment, Targa is building out its Delaware Express pipeline expansion and two new 150 MBbl/d fractionation trains in Mont Belvieu. The Pembrook II plant is expected online in Q3 2025.

pipeline projects in exchange for restarting offshore wind development. Trump halted the $5 billion Empire Wind project early in his presidency but has reportedly allowed it to proceed. In return, Hochul allegedly

EAGLE FORD

Renascent repurposes Eagle Ford shale well for geothermal energy Renascent Energy has successfully completed a geothermal test using a depleted shale gas well in the Eagle Ford formation in South Texas, demonstrating that legacy wells can be repurposed for clean energy production.

The test activated a large natural fracture system in the deep well without the need for new hydraulic fracturing. The project highlights the potential to convert inactive shale wells into geothermal energy sources, offering baseload renewable energy with minimal environmental impact.

Renascent says the demonstration opens the door for thousands of similar wells across the U.S. to be reused for geothermal development, reducing costs and leveraging existing infrastructure.

agreed to approve the Constitution Pipeline and Northeast Supply Enhancement (NESE) project. Hochul denies any quid pro quo.

Williams seeks NESE certificate reissuance

Williams has submitted a 246-page filing with FERC requesting expedited reissuance of a certificate for the NESE project, which would expand Transco pipeline capacity to supply Marcellus gas to New York City and the Northeast.

ODNR links Ohio earthquakes to fracking

Since April 22, at least five small earthquakes have been reported in Guernsey and Noble counties in eastern Ohio.

ROCKIES

Zephyr Energy

HAYNESVILLE

Black Stone signs Haynesville development deal with Revenant Black Stone Minerals LP has entered into a development agreement with Revenant Energy to accelerate drilling across its expanded Haynesville and Bossier Shale acreage in East Texas. The agreement covers approximately 270,000 gross acres across San Augustine, Nacogdoches, Angelina, Houston and Trinity counties.

Black Stone controls about 95,000 undeveloped net acres in the region and anticipates additional acquisitions. The agreement includes escalating annual well commitments, starting with a minimum of six wells in 2026 and rising to 25 wells per year. It also requires test wells in certain areas to maintain development rights across the full acreage position.

The Ohio Department of Natural Resources has linked the seismic activity to fracking at Encino Energy’s Bears Pad in Noble County and has ordered drilling to halt pending an investigation.

Williams promotes Transco expansions in Carolinas and Virginia

Williams has proposed two expansions of its Transco pipeline: Southeast Supply Enhancement, which would add 1.6 Bcf/d of capacity across North Carolina, and Power Express, which would deliver 950 MMcf/d to Virginia to serve growing power demand. The Power Express project is expected online in Q3 2030; regulatory filings are pending. CT2

reports strong Paradox Basin test results

Zephyr Energy plc reported promising initial production test results from its flagship well in the Paradox Basin in Utah. The well achieved a peak rate of 2,848 boe/d and sustained rates between 700 and 1,066 boe/d over a 48-hour period.

Fibre optic data showed hydrocarbon inflow across the entire lateral, suggesting a larger connected reservoir than initially expected. The company is analyzing fluid samples and expects to provide full recovery estimates soon, indicating broader development potential in the basin.

From extraction and gathering to compression, power generation, and final delivery, WPI is the engine behind North America’s natural gas infrastructure. Now, for the first time, we’ve mapped it all out for you to see.

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Anna Kachkova provides information on the latest gas compression news from Europe

GERMANY

SEFE signs 10-year gas import deal with Azerbaijan

Germany’s SEFE and Azerbaijan’s stateowned SOCAR announced in June that they had signed a 10-year natural gas purchase agreement. Under the deal, SOCAR

ANNA KACHKOVA is an independent oil and gas writer based in Edinburgh, Scotland. She has over 13 years’ experience of covering the energy industry, including five years in Houston, Texas, as NewsBase’s North America editor. Her email address is: aikachkova@gmail.com

will supply up to 15 terawatt-hours per year — equivalent to about 53 billion cubic feet (1.5 billion cubic meters) — starting in 2025 and gradually ramping up to the maximum annual volume.

The agreement comes as Europe continues to diversify away from Russian energy supplies in response to the war in Ukraine. Germany, which was heavily reliant on Russian gas at the start of the conflict in 2022, has since invested in alternative sources, including liquefied natural gas (LNG) import terminals.

SEFE said the deal would support investments in infrastructure such as gas compressors, boosting the amount

GREECE

DESFA launches hydrogen pipeline tender to Bulgaria Greek gas transmission system operator DESFA launched a tender in May for basic engineering design services for a proposed hydrogen pipeline to Bulgaria.

The project, known as H2DRIA, is expected to cost about 1 billion euros ($1.2 billion) and be commissioned by 2029. The design contract is valued at 1.5 million euros ($1.7 million) and will run for nine months. The proposed 570-kilometer (354-mile) pipeline would initially carry 80 gigawatt-hours per day of hydrogen. Running parallel to an existing high-pressure natural gas line, the pipeline would link hydrogen production centers in mainland Greece to demand hubs in Athens, Corinth and Thessaloniki. It would also connect to hydrogen infrastructure planned by Bulgaria’s Bulgartransgaz and could extend to North Macedonia.

The pipeline is part of the European Hydrogen Backbone and the South-Eastern European Hydrogen Corridor Initiative (SEEHyC), a regional network of hydrogen infrastructure being developed by TSOs in Greece, Bulgaria, Romania, Czechia, Hungary, Slovakia and Germany.

The H2DRIA pipeline would include two compressor stations with a combined capacity of 60 megawatts. The basic engineering phase will define the technical specifications, including routing surveys, process design, piping and instrumentation, electrical systems and civil drawings.

of pipeline gas reaching Europe and contributing to the continent’s energy security.

“With this partnership, we are establishing a new route for significant gas volumes to reach Europe, thereby diversifying our portfolio and increasing the security of supply for our customers,” said SEFE CEO Egbert Laege.

The deal was announced around the same time the European Commission proposed banning use of the Nord Stream pipelines between Russia and Germany as part of a new sanctions package. The pipelines, which were damaged by sabotage in 2022, remain offline. German Chancellor Friedrich Merz also ruled out restarting the Nord Stream 2 pipeline in May.

ITALY

SIAD MI to supply compressor for Falconara hydrogen project

SIAD Macchine Impianti (SIAD MI) said in late May that it will supply an oil-free high-pressure hydrogen compressor to the Falconara hydrogen project in Italy.

The project, led by Opificio Idrogeno Marche, aims to develop a green hydrogen production hub at the site of the former Montedison chemical plant in Ancona.

Scheduled for completion in 2026, the project will include a hydrogen refueling station for buses and cars.

SIAD MI said the compressor is in production and can achieve pressures up to 550 bar. It is the result of a long-term research effort focused on optimizing power consumption and extending

Routing of H2DRIA pipeline.

NORWAY

Hoerbiger to supply compressors for hydrogen hub

Hoerbiger announced in late May that it will supply two HCP 500 hydrogen compression packages to the Agder Hydrogen Hub under construction in Fiskå, Kristiansand, Norway.

The facility is being developed by Greenstat and its majority shareholder, La Française de l’Énergie. The 60-MW plant will produce green hydrogen via electrolysis powered by renewable energy, with operations targeted by the end of 2026. The hydrogen will be supplied to the local maritime sector.

Hoerbiger said the compression packages feature its electric stepless capacity control system, eHydroCOM, which provides efficient flow-rate control to match electrolyzer output and trailer-filling needs. The packages use Ariel’s KBH compressor and deliver more than 250 kilograms per hour, suitable for trailer-filling and heavy-duty refueling under varying operating conditions.

maintenance intervals, resulting in a lower total cost of ownership.

Opificio Idrogeno Marche is a joint venture between Renco and the Pollarini Group. According to Renco, the Falconara site is one of three planned “hydrogen valleys” in the Marche region. The initiative is supported by Italy’s National Recovery and Resilience Plan.

UNITED KINGDOM

Bilfinger wins Felindre compressor station upgrade contract

Bilfinger UK announced in late May that it has been awarded a contract by National Gas to carry out planned upgrades at the Felindre compressor station in Wales.

The work is part of the UK gas transmission operator’s Control System Refurbishment Project and is funded by the Office of Gas and Electricity Markets (Ofgem).

Bilfinger will act as both principal designer and contractor, overseeing design, engineering and construction.

The company said the design phase will involve 40 to 50 staff, with up to 100 personnel on-site during peak construction. Work includes the design and manufacture of control panels and other systems.

Bilfinger has already completed front-end engineering design for the project and been engaged in preparatory work for the past three years.

Each compressor station on the UK’s national transmission system contains two or more compressor units that ensure flow speeds of up to 25 miles per hour (40 kilometers per hour), Bilfinger noted. CT2

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Hoerbiger will supply two HCP 500 hydrogen compression packages to the Agder Hydrogen Hub under construction in Fiskå, Kristiansand, Norway.

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Kodiak invests in workforce with hands-on BEARS Academy

Program accelerates technician onboarding and builds real-world skills.

By Jack Burke

In an industry where field experience can take years to build, Kodiak Gas Services has created a fast track.

The company’s new BEARS Academy— short for “Building Experience and Real Skills”—is a hands-on training program designed to equip field technicians with the knowledge, confidence, and consistency

Training programs

Each year, COMPRESSORTech2 showcases companies and organizations that offer compressor-focused training programs.

Here’s a listing of some training opportunities available in the industry.

INNIO Group’s Waukesha engine training centers: Elevating engine expertise with state-of-the-art training

INNIO’s Waukesha Training Centers stand at the forefront of gas engine education, offering state-of-the-art hands on, augmented reality, animated, and virtual training programs designed to empower

Waukesha has recently integrated Augmented Reality (AR) into the training program offerings, allowing trainees to practice troubleshooting with real-world scenarios using a smartphone or i-Pad.

technicians, operators, and all other service and sales staff worldwide.

What’s new? Augmented Reality (AR) has recently been integrated into training program offerings, allowing trainees to practice troubleshooting with real-world scenarios and simulate elevated conditions in a controlled environment, where it’s safe to learn from mistakes. Using an iPad or smartphone, this technology enhances learning by providing immersive, hands-on experiences that improve understanding and retention of complex technical concepts.

INNIO’s Waukesha Engine Training Centers also feature advanced animations integrated into both classroom and e-learning modules. These dynamic visual tools make complex concepts easier to understand, increasing the value and effectiveness of every course. And in response to evolving industry needs, the Waukesha

Training Centers have introduced three new commissioning courses for the VHP, VGF, and 275GL+ engine series. The classroom portion of the Commissioning course verifies the technician has the technical competency to fully commission an engine in the field and complete the required documentation. .

Hoerbiger IQ

Hoerbiger IQ – Industry Qualification is the OEM-independent training program designed to guide participants through a comprehensive journey into the world of reciprocating compressors. With 24 topic modules divided into Introductory, Advanced, and Expert levels, the program delivers high-value learning for every role— from operators to reliability engineers, and even emissions reduction specialists. Training is offered in multiple formats: high-impact live online sessions, in-person sessions at global locations, or on-site at customer facilities.

Kodiak celebrated the ground-breaking for the new Midland facility, including BEARS Academy, in April 2025.

The BEARS Academy logo depicts the acronym and goal for the facility: to Build Experience And Real Skills.

Students complete one of several hands-on assessments at BEARS.

they need to thrive in the gas compression industry.

Launched in early 2024, the program compresses what used to be 18 months to two years of field training into a focused, three-month onboarding experience, featuring classroom instruction, lab work, and virtual reality (VR) simulations.

Our content is structured into 3 progressive Knowledge Sessions:

■ Getting to know – foundational compressor and component fundamentals

■ System knowledge – deep dives into core compressor systems and auxiliaries

■ Solving problems – focused on troubleshooting and resolving operational issues and the relationship between the compressor and plant process.

Each session is designed to elevate participants to the next level in just two days.

For those seeking hands-on experience, our immersive 4-day practical course uses operational 2-cylinder reciprocating compressors at training centers in Vienna, Jubail, Houston, Singapore, and Melbourne.

We welcome you to inquire about our planned training sessions at our various locations, including our brand-new Training Center in Houston.

⊲ RECIP.CustomerTraining@hoerbiger.com

Located in Monahans, Texas, the current BEARS Academy operates inside a repurposed field warehouse. But Kodiak is already building a larger, dedicated training facility in Midland, expected to open in 2026.

Melody Shulse, director of talent development and training at Kodiak, has overseen the academy’s development and rollout. She says the program fills a critical gap in the onboarding process for new hires—especially in an industry that relies heavily on field experience.

“Mechanics consistently tell us the best way to learn is hands-on,” Shulse said. “You can read manuals and watch videos, but until you physically tear something down and put it back together, you’re missing a huge part of the learning.” The integration of hands-on practice in a lab or shop environment following time spent in the classroom helps solidify concepts that once had to be learned in-the-field.

Accelerated training and consistency in the field

At the heart of the BEARS Academy is Kodiak’s Technician Fundamentals program, a three-week course divided

In an industry where precision, safety, and reliability are paramount, training is not just a necessity—it’s a strategic advantage.

Siemens Energy

In an industry where precision, safety, and reliability are paramount, training is not just a necessity—it’s a strategic advantage.

At Siemens Energy, our commitment to excellence in operations and maintenance (O&M) training continues to evolve, now incorporating the latest in digital innovation to better serve our global workforce.

Strategically located training centers: Strategically located in Houston, Texas,

into three levels—BEARS One, Two, and Three—delivered over a 90-day period. Each technician completes a one-week session at the academy, returns to their assigned location to work with a mentor, and then returns the following month for the next session. By the end of the third month, they undergo both written and hands-on evaluations to confirm their readiness for full-time field work.

The structured timeline helps new hires build a consistent knowledge base while gaining confidence through repetition and practice.

“We built the program to ensure every technician receives the same experience and foundational knowledge,” Shulse said. “It doesn’t matter whether they come in with zero experience or 20 years—everyone goes through the program. That allows us to set expectations and reinforce Kodiak’s standard operating procedures from day one.”

Training that builds community and culture

Beyond technical skills, BEARS fosters connection and shared identity. Each training cohort—typically 20 to 30 >

and Duisburg, Germany, our training and competence centers have long been recognized for their immersive, hands-on learning environments.

CECO

Compressor Engineering Corporation (CECO) Training & Technical Services instructor-led training provides the knowledge, skill, and expertise needed to operate, maintain, and analyze the health and performance of your equipment. Instructor-led training provides the expertise and experience of CECO’s knowledgeable trainers. They are available to answer questions as they arise and guide instruction tailored to each client’s very specific needs. The benefits of a knowledgeable instructor bring great value to CECO’s training classes that printed workbooks and web-based training alone cannot provide.

We recognize no two companies are exactly alike and neither are your training >

Students in the classroom gain knowledge through theory-based presentations.

PARTNERS IN TRAINING

TECHNICAL SKILLS

technicians—moves through the program together, creating a support system that extends beyond the classroom.

“It’s easy to feel isolated early in your career, especially in remote field locations,” Shulse said. “But when you go through BEARS, you have a peer group from all over the company. That sense of community makes a difference in engagement and retention.”

Veteran technicians, even those with years of experience, benefit too. They often play an informal mentoring role in the classroom, strengthening their leadership skills and reinforcing their own expertise.

“We’ve had techs with decades in the field say, ‘I wish I had something like this when I started,’” said Shulse. “Some of them come in thinking they’ll just be reviewing the basics—but they end up learning something new or sharpening skills they haven’t used in a while.”

Virtual reality adds dimension

Kodiak was an early adopter of virtual reality, but BEARS Academy provided the structure to make the most of it. Technicians now learn how to use VR headsets during their first week at BEARS, gaining access to modules that simulate SOPs such as lockout/tagout, startup and shutdown procedures, and basic component identification..

“When they go back to their location, they already know how to use the headset,” Shulse said. “And that’s when the real value shows up—when they voluntarily practice SOPs because they’ve seen the benefit.”

VR allows for safe, repeatable practice of high-risk tasks and helps new hires learn equipment layouts before they step into the field. Kodiak is continuing to develop more advanced VR modules and exploring augmented reality tools that could assist field techs in real time.

needs. We will work with you to create a customized course that will satisfy specific training needs for your company. You can choose to have one of our expert instructors lead the customized course or we can create a trainer’s kit to allow one of your own subject matter experts to lead the class. The trainer’s kit includes lesson plans, presentations, and presenter´s notes, providing your SME with the necessary tools to teach the customized course.

⊲ Check us out on the web at www.tryceco.com.

STASSKOL

STASSKOL offers specialized training for spare parts in reciprocating compressors. The training includes the basics of sealing technology; all about piston rings and rider bands, piston rod packings, intermediate packings and oil wiper packings; the basics of packing construction; the basics of packing repair; and the selection of ideal

material. STASSKOL also offers individual training on special topics.

Dr.-Ing. Andres Laschet

Dr.-Ing. Andreas Laschet is a German office that offers engineering services, technical consulting, and special customer training in various areas of drive technology. The training courses cover the entire field of torsional vibration analysis (TVA) and optionally also the rotordynamic calculation and evaluation of complete shaft systems in rotating machinery. The training program can be put together according to the customer’s wishes.

Dr. Laschet offers customer support mainly for the European market – also in cooperation with Concepts NREC (US).

⊲ More information: www.laschet.com

FW Murphy Production Controls

FW Murphy Production Controls provides in-depth training to help users maximize the

Safety and service

Safety is a central pillar of BEARS. Technicians are trained on Kodiak’s standard operating procedures from day one, and they are expected to carry field binders with printed SOPs when working with their mentors.

“We believe a trained workforce is a safe workforce,” Shulse said. “The better we train, the fewer issues we see in the field—and that translates directly into better uptime and better service for our customers.”

As Kodiak grows, having a centralized training approach has also helped the company maintain consistency across its footprint. Before BEARS, different regions developed their own onboarding methods. Now, every technician starts with the same foundation.

benefits of their engine control products. Custom, on-site training is available, as well as a variety of standard topics, including Engine Basics, IntelliSpark Ignition, AFR Operations, EICS Operations, EICS-VHP Operations, Centurion Operations and M-Link Usage. In-person training includes hands-on learning with small classes. Virtual options are also available.

Ebara Elliott Energy

Ebara Elliott Energy’s turbomachinery training programs range from basic fundamentals to advanced topics. Its experienced, full-time trainers conduct customized training programs focusing on steam turbines, centrifugal and axial compressors, expanders, lube and seal systems, and cryogenic pumps and expanders. The company offers training onsite at customer locations around the world, at its own facilities, or through many “live” online courses.

A cohort celebrates the successful completion of the Technician Fundamentals program at BEARS Academy.

Trainers give a tour of the shop environment to a new cohort, familiarizing them with the equipment available and the types of activities they will complete during the program.

More than onboarding

While BEARS currently focuses on onboarding technical skills and procedures, Kodiak views it as the foundation of a broader workforce development strategy. The new Midland facility will offer the space and resources to expand training beyond new hires.

“Our goal is to make Bears Academy a full lifecycle learning center,” Shulse said. “It’s not just about getting people in the door—it’s about helping them grow their entire careers here.”

Kodiak is also developing a modified

BEARS experience for corporate staff and new leaders. That version of the program will introduce non-technical employees to the fundamentals of field operations, giving them hands-on exposure to the equipment and processes their decisions impact.

“If you work in safety, HR, or logistics, it helps to understand what our technicians face in the field,” Shulse said. “We want our entire organization to speak the same language when it comes to field operations.”

An edge in recruiting and retention

With labor competition still high across the energy sector, Kodiak believes BEARS gives it a recruiting advantage. The company pays for all training, travel, and lodging costs and guarantees new hires a structured development plan from day one.

“Technicians want to know they’re going to be supported, that they’ll have the training and tools to succeed,” Shulse said. “BEARS shows them that we deliver on that promise, and put our resources behind our words .”

Field leaders also benefit. Instead of trying to train every new hire individually, they can rely on the academy to deliver consistent instruction, freeing them to focus on mentoring and operations.

Building tomorrow’s workforce, today

Kodiak’s investment in BEARS is more than a short-term training solution—it’s a signal of long-term commitment to its workforce and the gas compression sector.

“We’re not just building a program. We’re building a pipeline of talent,” said Shulse. “Whether someone stays with us for five years or twenty, we want their time at Kodiak to be a career—not just a job.”

JOIN US IN HOUSTON FOR OUR GRAND OPENING EVENT SEPT 15 SIGN UP. SHOW UP. WIN GEAR.

CT2

As the energy industry evolves and competition for skilled labor intensifies, Kodiak believes the BEARS Academy will remain a central part of its growth strategy— and a differentiator in how it trains, retains, and develops the next generation of gas compression professionals.

Storing hydrogen

Hydrogen storage is heating up — and Neuman & Esser is building the compressors to handle It.

By Jack Burke

When it comes to industrial compression technology, Neuman & Esser (NEA) isn’t thinking small. At a recent industry event, Joseph Lesak, Sales Manager at NEA, painted a compelling picture of how the energy landscape is shifting — and how compression technology is evolving to meet those changes.

Lesak made his remarks at Neuman & Esser’s Customer Day event at its Katy Production Center. Company experts provided technology updates, offered a tour of hydrogen electrolyzers and compressors in production as well as a visit to Custom Heliarc’s new packaging facility in Brookshire, Texas.

Bigger compressors for a bigger energy challenge

The focus of Lesak’s talk was a massive hydrogen storage project in Europe — one driven by the geopolitical upheaval of recent years. With the war in Ukraine disrupting the continent’s access to Russian natural

itself is simpler (pure hydrogen is easier to model than complex gas mixes), the operational challenges are far greater.

gas, European countries have been forced to rethink their energy strategies. One emerging solution: large-scale hydrogen storage.

Hydrogen, long considered a promising but complex energy carrier, is now moving from concept to reality. And storing it safely, efficiently, and at scale requires compressors unlike any currently in operation.

Lesak explained how this new project involves installing four enormous, foundation-mounted reciprocating compressors — each driven by a staggering 25,000-horsepower motor. These aren’t the compact packaged systems often seen in industrial plants. These are customengineered, high-pressure, high-capacity machines, purpose-built to inject and withdraw hydrogen from underground storage caverns.

A new set of technical challenges

Moving hydrogen isn’t like moving natural gas. Lesak emphasized that while the gas

Hydrogen requires a compressor system that can manage extremely broad pressure and flow ranges, often within a single duty cycle. That makes the reciprocating (or “recip”) compressor a smart choice — especially one with what Lesak called “rubber band” flexibility, able to stretch between high and low loads seamlessly.

Beyond performance, safety is paramount. Hydrogen is highly prone to leakage, and its small molecular size makes it harder to contain. NEA’s compressors for this project feature specialized static packing that seals the machine once it stops, minimizing fugitive emissions. There are also extensive pulsation and piping studies involved to ensure system integrity under fluctuating loads.

Efficiency that matters

One standout statistic Lesak shared: these compressors achieve 97% adiabatic efficiency when storing and withdrawing hydrogen — a level of performance that helps make hydrogen a more commercially viable energy option.

Neuman & Esser held a Customer Day event at the company’s Katy, Texas, Production Center.

Why does this matter? Because hydrogen remains expensive compared to other fuels, and efficiency gains like this help drive down the overall cost of storage and distribution.

Engineering for the unknown

Perhaps the most intriguing aspect of this project is its experimental nature. Lesak acknowledged that starting and stopping machines of this size — especially when

running intermittently based on hydrogen supply and demand — is largely uncharted territory.

Europe is under pressure to innovate, and projects like this are breaking new ground in energy infrastructure. As Lesak put it, while the U.S. still enjoys a relatively stable natural gas market, European nations are urgently testing new technologies, hoping to build a reliable, renewable-driven grid backed by large-scale hydrogen storage.

More than a compressor

Lesak closed with a message for engineers and project managers: in hydrogen projects, the compressor is just one piece of a highly complex puzzle. Piping design, safety systems, control schemes, and adherence to industry standards like API 618 are just as critical.

His advice? Treat these standards like a bible — they’re written from the lessons learned on projects just like this. CT2

Mechanical Pin PLDs

A visual indicator (pin) extends, in response to packing leaks.

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A rendering of the H2

European hydrogen infrastructure struggles to pick up momentum

Plans to develop clean hydrogen supply chains across Europe face a range of obstacles. Although some progress has been made, it remains insufficient to meet the European Union’s goal of producing 10 million metric tons of renewable hydrogen by 2030 — alongside importing another 10 million tons.

The challenges affect both blue hydrogen — produced from natural gas with carbon capture and storage — and green hydrogen, made by electrolysis powered by renewable energy. These obstacles include technical, financial, market, and regulatory issues.

Pipeline infrastructure to connect hydrogen production with demand hinges on certainty that production projects will proceed. Yet, production projects depend on pipeline infrastructure to be viable, creating a classic chicken-and-egg problem.

To accelerate clean hydrogen development, coordinated action from governments, regulators, industry, and the EU is critical. Without it, hydrogen’s role in Europe’s energy mix risks being far smaller than planned.

One step forward, two steps back Progress on hydrogen infrastructure has been slow and uneven. Morningstar

Plans to build new clean hydrogen infrastructure in Europe have hit multiple setbacks, raising doubts about whether the continent will meet its ambitious targets.

By Anna Kachkova

Sustainalytics stewardship managers Marta Mancheva and Amar Causevic say advances in 2024 have been “much slower” than expected.

“Industry optimism going into 2024 gave way to modest advances and notable delays,” they told COMPRESSORTech2 in writing.

While some final investment decisions (FIDs) have been made and new hydrogen strategies announced, overall momentum is falling short of targets. Mancheva and Causevic noted major players like France’s Engie have pushed back timelines, delaying

Green Steel largescale green steel plant in northern Sweden. IMAGE: STEGRA

their 4-gigawatt green hydrogen capacity target from 2030 to 2035.

Ben Clark, senior analyst at Westwood Global Energy Group, said production projects have fared better than pipelines but still lack scale.

“In Q4 2024, only one project took FID with 100 megawatts capacity, while eight projects totaling 4.7 gigawatts were stalled or canceled,” Clark said. “It feels like one step forward, two steps back.”

Several pipeline projects, especially in and around Germany, have seen delays or cancellations. Germany’s planned 9,700-kilometer hydrogen network, estimated at 20 billion euros ($22.6 billion), was delayed five years to 2037. Equinor scrapped plans to export blue hydrogen from Norway to Germany. Denmark

postponed a green hydrogen pipeline to Germany by three years, to 2031.

In the UK, BP canceled the 500-megawatt HyGreen Teesside project in March 2025 after stopping 18 early-stage hydrogen projects globally in 2024.

Obstacles holding back hydrogen Analysts point to several key reasons for delays and cancellations.

Emma Keisser, hydrogen associate at Aurora Energy Research, said a major hurdle is the lack of long-term offtake agreements — contracts that guarantee buyers for hydrogen.

“Securing 15-year or longer offtake agreements is crucial but difficult,” Keisser said. “Producers need stable demand to justify investments, and electrolyzers face competition for renewable energy, complicating consistent production.”

She also cited a lack of project guarantees for lenders, the challenge of developing many parts of the hydrogen value chain simultaneously, and high market

The GET H2 Nukleus project connects the production of green hydrogen with industrial consumers in Lower Saxony and North Rhine-Westphalia. The approximately 130-kilometer network from Lingen to Gelsenkirchen is set to become the first H2 network in the regulated sector with non-discriminatory access and transparent prices.

prices relative to gray hydrogen despite subsidies.

“Offtakers want low-cost hydrogen, but current prices remain high, so they hesitate to commit,” Keisser said. “This interdependence among projects, technologies, and customers creates uncertainty, slowing investment decisions.”

Morningstar’s Mancheva and Causevic highlighted high production costs, funding gaps, and limited demand as structural challenges.

“High costs have led to project cancellations like Equinor’s 10-gigawatt Clean Hydrogen to Europe initiative, scrapped due to pipeline and carbon capture costs,” they said. “Even major players struggle without lower costs or more public funding.”

They also said complex EU subsidy schemes may deter investment.

“Navigating the EU’s hydrogen auction rules has caused withdrawals, even from initially subsidized green hydrogen projects,” they said.

Regulatory and permitting complexity also slows progress. “The EU’s strict criteria for renewable fuels of non-biological origin (RFNBO), essentially green hydrogen, are seen as bureaucratic >

barriers,” Mancheva and Causevic said. The European Court of Auditors criticized the EU hydrogen targets in July 2024 as unrealistic and lacking binding national commitments, especially where permits require multiple layers, such as in Italy.

Demand uncertainty compounds the problem.

“Cancelled projects often lacked offtake commitments because buyers were unwilling to pay a green premium,” Mancheva and Causevic said. “Without longterm buyers like refineries or steelmakers, projects can’t secure financing.”

Clark of Westwood confirmed the same issues.

“High costs, economic challenges, funding failures, and lack of demand are main reasons for project cancellations or stalls,” he said. “Confusing funding and slow infrastructure development make hydrogen cost-competitive only in the long term.”

Clark added that Europe’s focus on production has sometimes left demand behind.

“Without mandates to encourage buyers, projects can’t secure offtake agreements, leading to cancellations,” he said.

The expected role of hydrogen in sectors like road transport and home heating is also shrinking compared with initial hopes.

Morningstar estimates nearly 29 gigawatts of planned clean hydrogen capacity was stalled or canceled in 2024, about one-fifth of the total. Westwood’s 2025 white paper echoes this. In Q1 2025, Westwood reported 13 announced projects totaling 2.5 GW and three projects reaching FID, but also two cancellations totaling 1.1 GW.

Westwood now forecasts that only 17% of the EU’s planned hydrogen projects will be realized without stronger market intervention.

Intervention options

Market interventions could reverse the trend, but they must be rapid, coordinated, and decisive.

Westwood’s white paper identifies three key levers to unlock hydrogen potential: clear policy frameworks, effective funding mechanisms, and strong demand mandates.

Clark says EU rules like RFNBO are unlikely to be revised before 2028 but expects a new delegated act on low-carbon hydrogen with carbon capture to be introduced in 2025.

“Streamlining funding and permitting could speed project development,” Clark said.

Funding is shifting from production to offtake and sector focus, but demand creation still struggles due to multiple overlapping EU mandates.

“We need robust incentives for both supply and demand,” Clark said. “Governments must support producers and consumers through subsidies and consumption mandates.”

Morningstar agrees that streamlined rules and targeted subsidies are critical.

“Faster permitting and harmonized

EU regulations can boost confidence,” Mancheva and Causevic said. “Contractsfor-difference and risk-sharing can close cost gaps. Public-private partnerships and innovation funding for electrolysers will help. Co-ordinated infrastructure planning is essential.”

Aurora believes early success in large projects would build investor confidence.

“Shifting financing toward debt is key to unlocking investments,” Keisser said. “But investors need policy clarity and bankable project examples.”

Keisser also sees non-compliance penalties and consumption subsidies as incentives for offtakers.

The consensus is clear: carrots alone may not work; sticks like mandates and penalties may be necessary to boost hydrogen demand.

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HYDROGEN INFRASTRUCTURE

Bright spots amid challenges

Despite setbacks, some projects show promise.

Germany remains a hydrogen leader. Uniper’s 131-megawatt Green Hydrogen Wilhelmshaven project began pre-frontend engineering design in 2024, secured an electrolyzer provider, and found offtake buyers in the green steel sector.

TotalEnergies signed a long-term deal in March 2025 to buy green hydrogen from RWE’s GET H2 Nukleus project to decarbonize its Leuna refinery.

“Refineries are becoming key green hydrogen buyers in Europe,” Keisser said.

The German Core Network, a major hydrogen transport initiative, is also a key development to watch.

H2 Green Steel (renamed Stegra) in Sweden secured debt financing, equity funding, and an EU grant, showing renewable hydrogen’s potential in steel decarbonization.

Mancheva and Causevic highlighted H2

Green Steel along with other bright spots: the H2Med pipeline linking Spain, France, and Portugal aiming for 2030 operation; and large electrolyzer projects like BP’s Castellón, Shell’s REFHYNE II, and EWE’s Clean Hydrogen Coastline, which reached FIDs in 2024.

“Hydrogen valleys like HySynergy in Denmark are already operational, supplying near-shore industries,” they said.

Aurora said early renewable hydrogen use will focus on decarbonizing industries that already use gray hydrogen. Later, synthetic fuels could drive demand in hardto-abate sectors like maritime and aviation.

Falling short of targets

capacity to meet targets.

“Countries like the UK, Spain, and Germany have large project pipelines but also many ‘risked projects’ that may not materialize,” he said.

Speakers

Vasant Saith

The EU is at risk of missing its 2030 hydrogen production and import targets.

“At the end of 2023, Europe used about 7 million tons of hydrogen, 99% fossil-based,” Mancheva and Causevic said.

Clark noted that some countries, including Portugal and Sweden, lack

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Clark suggested the EU could boost subsidies in refining, fertilizer, and steel sectors, speed up permitting, increase imports, and provide new offtaker incentives. Mancheva and Causevic expect the EU to respond by scaling up investments, imposing binding mandates in key industries, and focusing on viable hydrogen uses.

Keisser warned incentives alone might

Sanjeev Daruka

Head of Global LNG, Siemens Energy

“The EU may need stricter penalties for non-compliance on renewable hydrogen consumption,” she said.

She stressed the need for early, successful hydrogen projects to build confidence.

“There is interest and ambition, but investor confidence is lacking,” she said. CT2

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Baker Hughes said its new advanced flame detection technology, Flame Tracker Increased Low Gain (ILG), is designed to enhance flame sensing capabilities on gas turbines.

Baker Hughes introduces advanced flame detection sensor for gas turbines

New Flame Tracker ILG enhances reliability, supports hydrogen blends in midstream operation.

Baker Hughes has launched a next-generation flame detection sensor designed to improve flame monitoring accuracy and response time in gas turbine systems—a critical advancement as the midstream sector increasingly integrates hydrogen blends into fuel streams.

The new product, Flame Tracker Increased Low Gain (ILG), is part of the company’s Reuter-Stokes instrumentation portfolio. It was unveiled May 15 and is manufactured at Baker Hughes’ longtime Reuter-Stokes facility in Twinsburg, Ohio. The Flame Tracker ILG is designed for high sensitivity in low-light conditions, offering a significant reliability upgrade over its predecessor, particularly in demanding operational environments.

Essential components

Flame sensors are essential components in gas turbines, serving as the primary safety mechanism to confirm flame presence during combustion. They play a critical

role in preventing equipment damage and safety hazards by detecting flame instability or loss and triggering rapid shutdown protocols. However, the performance of these sensors can degrade when light levels are diminished due to condensation, lens fouling, or challenging sight line conditions.

Enhanced light sensitivity

According to Baker Hughes, the Flame Tracker ILG addresses these challenges through enhanced electronics that improve light sensitivity. The system can detect flame presence in less than 0.025 seconds and maintain performance even in applications where the flame view may be partially obstructed.

“Fuel flexibility and combustion stability are top of mind for our customers, especially as they evaluate hydrogen blends in their operations,” said a company spokesperson. “This technology builds on more than two decades of flame sensor innovation, giving operators a reliable, fieldready solution that’s compatible with new fuel strategies.”

Hydrogen-enriched natural gas blends are gaining traction as a pathway to reduce greenhouse gas emissions from midstream and power generation infrastructure. But using these blends introduces complexities in combustion monitoring due to hydrogen’s distinct flame characteristics. By extending flame detection capability to lower thresholds, the Flame Tracker ILG is intended to mitigate risk while enabling decarbonization efforts.

Retrofit option

The launch reinforces Baker Hughes’ commitment to supporting energy transition technologies without compromising safety or operational efficiency. The company said the Flame Tracker ILG is available for both new installations and retrofit applications across a range of turbine platforms.

The product is the latest in a series of innovations emerging from Baker Hughes’ Reuter-Stokes brand, which has been supplying sensing and measurement technology to the energy industry for over 25 years.

“Fuel flexibility and combustion stability are top of mind for our customers, especially as they evaluate hydrogen blends in their operations.”

CT2

IMAGE: BAKER HUGHES

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Turbomachinery: The backbone of progress

By Tyler Courtney

Turbomachinery is at the heart of many major industries, including power generation, oil refining, critical standby power, and even marine vessels like cruise ships and aircraft carriers.

These machines are pivotal in ensuring smooth operation to critical infrastructure that keeps the world moving. However, the unwavering demands placed on turbomachinery components to perform lead to inevitable wear and tear which poses significant challenges to maintenance and operational efficiency.

Couplings play crucial role

Among the many components within turbomachinery design, couplings play a crucial role in connecting and supporting critical equipment. Despite their importance, couplings are often overlooked in maintenance plans.

High-performance couplings are designed for extremely long operation cycles when operated within their rated capacities. However, real-world conditions often introduce less than ideal conditions which lead to potential failures, unplanned downtime, and expensive repairs to your equipment.

AUTHOR

TYLER COURTNEY, director energy sales at Regal Rexnord

Damage down the line

The repercussions of coupling failures extend beyond their immediate repair costs. Unscheduled downtime can easily disrupt production and operation schedules, leading to substantial financial losses and operational inefficiencies.

In some severe cases, coupling failures can damage additional critical equipment, further escalating repair costs and downtime. Proactive maintenance of couplings is essential to safeguard the overall performance and reliability of turbomachinery.

Due to the critical issues caused by downtime with coupling repairs, operations have started keeping spares on hand for easy replacements.

By ensuring on-site replacements are available for immediate use, substantial downtime is subverted while repairs and maintenance can be done on the damaged components.

Recertification – the best of both worlds

Coupling recertification has emerged as a viable solution to address the challenges posed by standard wear and tear without needing a complete replacement. This process involves returning used couplings to the factory for reconditioning to a ‘like new’ condition at a fraction of the cost of buying replacements.

The recertification process includes comprehensive mechanical and metallurgical evaluations, replacement of

fixable elements, and rebalancing to original certification standards. This approach not only restores the coupling’s performance but also extends its service life ensuring continued reliability on the jobsite.

Monitoring software as a catalyst

Utilizing the recertification process requires the ability to tell when your equipment may be affected or trending towards complications. Advanced monitoring systems like Powerlign® further support proactive maintenance by detecting potential problems early. Within the turbine industry for example, these systems can monitor turbine performance and predict issues such as blade fouling and reduced system efficiency, enabling timely interventions before damage escalates to more severe problems, or increased fuel burn down the line.

Savings and efficiency

The benefits of coupling recertification are paramount. It offers substantial cost savings, and with recertified couplings costing about half the price of new ones, these savings can factor into your initial and overall investment into your operation. In addition, the lead time for recertification is significantly shorter, sometimes up to 60% faster than acquiring new couplings in some cases. This expedited process helps maintain operational schedules and minimizes downtime.

Coupling recertification can also reveal underlying issues in other equipment. For

instance, disc pack fretting or cracks in the outer disc may indicate resonant torsional frequency or excessive misalignment. Having a team to assess and identify these issues during recertification allows for timely modifications to the coupling and powertrain design, enhancing future performance and mitigating risks.

The future forward

Understanding common wear and tear in turbomachinery is crucial for the success of operations everywhere. Incorporating coupling recertification and smart monitoring systems into maintenance plans can significantly enhance the reliability and efficiency of your machines

and operation. Industries can proactively address issues, ensuring the longevity and optimal performance of turbomachinery components.

These advancements not only offer substantial cost savings but showcase the way for a more efficient and sustainable future.

CT2

Couplings play a crucial role in connecting and supporting critical equipment.

CORNERSTONES COROLLARY: EVOLUTION OF PIPELINES AND COMPRESSOR STATIONS

The Cornerstones of Compression series has highlighted many significant products over more than 160 years of continuous progress. This is the first of six Cornerstones of Compression corollary articles that provide a look back at the evolution of natural gas pipelines and compressor stations. By Norm Shade

The first natural gas pipelines

Largely hidden from view, a cornerstone of the natural gas compression industry was the development of safe, reliable pipelines. In the early days of U.S. oil patch development, gas was a waste product unless it could be used near the well that produced it. Enormous gas wells were discovered, but gas was viewed as a “worthless commodity” that was flared or simply allowed to escape to the atmosphere. The idea of piping it over long distances to make it a marketable commodity had not been conceived.

The first oil pipeline was a 5-mile (8-km), 2-in. (51-mm) diameter wrought iron pipe constructed in 1865 near Pithole, Pennsylvania. Though initially ridiculed, pipelines competed with the railroads and teamsters transporting oil in those days. John D. Rockefeller said the whole industry would have been held back without the development of pipelines.

Since natural gas could not be contained in a barrel and hauled, development of underground pipelines was necessary for reaching distant markets.

Made of wood

The first gas pipelines were made of wood, beginning in Fredonia, New York in 1821. In 1823, gas bubbling out from along

the south shore of Lake Erie was captured and piped through pine logs to a lighthouse. Wooden pipes were used for manufactured gas in several New York cities as early as 1854, with some still in service as late as 1929.

The genesis of thousands of miles of long-distance underground pipelines throughout the U.S. began with a bold experiment that failed miserably. In 1870, work began on a 25-mi. (40-km) pipeline

from West Bloomfield to Rochester, New York.

Large iron pipe was rare at the time and steel pipe didn’t exist yet, so hollowed out pine tree trunks were used. Bands of iron were shrunk around 2 to 8-ft. (0.6 to 2.4-m) long hollowed out logs, which were coated inside and out with tar.

Joints were sealed by dipping the end of a log in hot tar and driving it into another log. Wooden logs had little flexibility, so

FIGURE 1 Hollowed log gas pipe with iron gate valve.

CORNERSTONES OF COMPRESSION

turns were very gradual. Iron gate valves were inserted in the line at frequent points, an example of which is shown in Fig. 1, excavated after years of service.

As the New York project progressed, gas flowed along the pipe, and as each valve was placed, it was closed to hold back about 8 psig (0.6 bar) for leak tests. Valves were not closed tight, fearing that the well pressure might blow the line apart. Leaks were repaired by wrapping pipe with tar-soaked strips of burlap or surplus Civil War blankets, secured in place by two half rings of iron bolted together.

The project was a major engineering feat at the time. At first, there were few leaks, and a good flow of gas at a suitable pressure was carried to within 5 mi. (8 km) of Rochester. Then, high pressure built up and the pipeline blew apart.

The line was eventually completed to reach Rochester in 1872. But it was plagued by leaks and by water and mud seeping into the line and freezing. When demand was low, pressure would build up and burst the pipes. The line was soon abandoned.

First use of iron pipe

The first use of iron pipe for a “long distance” gas line occurred in 1872. Cast iron pipe had been around since the 1840s, and cast and wrought (ductile) iron pipes of various diameters were commonly used at oil well sites. A 2 in. (51 mm) wrought iron pipeline from Newton to Titusville, Pennsylvania enabled 90 psig (6.2 bar) wellhead

1821

The first gas pipelines were made of wood, beginning in Fredonia, New York.

1865

The first oil pipeline was a 5-mile (8km), 2-in. (51-mm) diameter wrought iron pipe constructed near Pithole, Pennsylvania.

pressure to push gas about 5 mi. (8 km).

In 1876, a 17 mi. (27 km), 6 in. (152 mm) cast iron gas line was laid from Butler County to Etna, Pennsylvania to supply an iron works at a pressure of 119 psig (8.2 bar). Other iron and steel works in Pittsburgh were supplied in the 1880s by new pipelines flowing from area wells, including one that George Westinghouse had drilled on his estate. Harper’s Magazine in 1886 reported that natural gas in Pittsburgh was already displacing over ten thousand tons of coal daily.

In 1885, Rockefeller interests laid an 8 in. (203 mm) wrought iron line from Oil City to Titusville, part of which remained in service for 70 years. In 1889, the Equitable Gas Company fabricated a 21 mi. (34 km), 36 in. (914 mm) pipeline from 0.25 in. (6.4 mm) steel plate, riveted together and caulked to prevent leakage.

In 1886, an 87 mi. (140 km), 8 in. (203 mm) wrought iron line with threaded couplings

1872

The first use of iron pipe for a “long distance” gas line occurred.

1886

An 87 mi. (140 km), 8 in. (203 mm) wrought iron line with threaded couplings was built from Kane, Pennsylvania to Buffalo, New York.

Tong gangs screwing together lengths of iron pipe, c. 1900.

was built from Kane, Pennsylvania to Buffalo, New York. It was still in use in 1973, when it was “renewed” by inserting a 4 in. (102 mm) plastic line inside it. A parallel 8 in. (203 mm) line in 1898 used Dresser couplings instead of threaded joints for the first time. These “self-packing” couplings with rubber seals, developed by Solomon R. Dresser, allowed this pipeline to operate at 250 psig (17.2 bar).

Labor intensive

Construction of early pipelines was very labor intensive. Pipeline trenches were dug with picks and shovels. Workers swinging eight-pound hammers onto a drill shaft cleared rocks and made tunnels under hills of solid rock. Once the random lengths of iron pipe were hauled in with teams of mules pulling wagons or sleds, they were screwed together and tightened by tong gangs as shown in Fig. 2.

It took almost 70 years after discovery of the first gas well in Fredonia, to figure out how to transport gas more than 100 mi. (161 km).

In 1891, two parallel 120 mi. (193 km), 8 in. (203 mm) threaded wrought iron pipelines were constructed from near Greenwood, Indiana with wellhead pressure of 525 psi (36.2 bar) to Chicago, Illinois.

Soon after 1900, natural gas spread to industrial centers like Cincinnati, Cleveland, and Toledo, Ohio. CT2

1891

Two parallel 120 mi. (193 km), 8 in. (203 mm) threaded wrought iron pipelines were constructed from near Greenwood, Indiana to Chicago, Illinois.

1900

Natural gas spread to industrial centers like Cincinnati, Cleveland, and Toledo, Ohio.

FIGURE 2

25 to 500 Bar at 250kg/hr

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