James Cook

ION Clean Energy (ION) has entered an agreement to bring its ICE-31 solvent technology to be validated at Technology Centre Mongstad (TCM), a carbon-capture test facility, to assess the product’s performance through parametric and steady-state testing to demonstrate the solvent’s stability and minimal degradation.

"TCM is a testing ground for carbon capture technologies, and we're excited to return and further prove the performance of ICE-31," said ION Chief Technology Officer, Erik Meuleman, Ph.D. "We're excited to get back to Norway and continue our efforts to deploy ICE-31 commercially as we all work towards a shared goal of net-zero carbon emissions."

The joint initiative assists ION’s commercial development program in taking the ICE-31 solvent’s technology readiness level (TRL) from TRL 6 to TRL 7, pending the success of validation testing. Upon ClearSign’s successful testing of the ICE-31 solvent, financial risk will have been mitigated due to the product’s performance within the upscaled validation parameters at TCM. In addition to ensuring the performance of ICE-31, the agreement between ION and TCM will enable the collection of process data to further verify the technology.

TCM can demonstrate the efficacy of these technologies so that an appropriate TRL rating may be applied. ION’s ICE-31 testing is set to begin in October of this year and span four months.

Articles

Technology Centre Mongstad welcomes ION Clean Energy to its facility for the testing of ICE-31’s stability and degradation. 

ION Clean Energy to Test ICE-31 Solvent at Technology Centre Mongstad

At Turbomachinery & Pump Symposia (TPS) 2023, 

 interviewed Todd Gerstendberger, Global Product Manager at ITT Goulds Pumps, about the company’s focus at this year’s show, what they are showcasing, and what they are most excited about.

He discusses solutions for pumping and fluid handling in the oil and gas industry and talks about the company's oil filter on its new 3700 product.

ITT's VS6-style pump is built with the wet end as a tie-rod style impeller and diffuser. “What we've found is if you take that same type of arrangement and hang it on end, gravity and also the down thrust of the pump pulls everything straight and keeps everything in line. A VI CR style of product [can support] 34 and 35 stages," Gerstendberger said. 

He also said it can handle a lot of pressure.

The company also introduced an upgrade to its 3700 product, highlighting the oil filter that filters out contaminants and pulls moisture out of the oil.

Videos

At TPS 2023, Turbomachinery International spoke with Todd Gerstendberger, Global Product Manager at ITT Goulds Pumps. 

Video: At TPS 2023 with ITT Gould Pumps

ClearSign Technologies Corporation (ClearSign) has announced a collaboration with and funding commitment from Southern California Gas Co. (SoCalGas) for its 100% hydrogen ultra-low NOx burner project.

The financial support pledged by SoCalGas comes in addition to the SBIR program Phase 2 Award for $1.6 million granted by the DOE. Funding will be allocated toward the project to decarbonize hard-to-electrify industries as it enters the commercialization phase. SoCalGas has pledged $500,000 for the introduction and field demonstration of hydrogen-capable ClearSign Core burners in Southern California.

"We are pleased to receive this support from the team at SoCalGas,” said Jim Deller, Ph.D., Chief Executive Officer of ClearSign. “We believe our collaboration with SoCalGas provides not just additional financial support but also their engagement with us in moving the energy transition forward in Southern California and making our ClearSign Core technologies part of the technical portfolio available to all the industries that SoCalGas serves.”

ClearSign aims to develop ultra-low NOx hydrogen burner technology to enable the adoption of hydrogen fuel for industrial heating, offsetting emissions of both CO

 and NOx. Decarbonization of industrial combustion processes is held back by the lack of burners capable of burning pure hydrogen and minimizing NOx emissions.

Phase 1 of the project featured the deployment of a prototype burner that integrated hydrogen and hydrogen blending while limiting NOx to below 5 ppm. Phase 2 will upscale the size of the burner from 2 MMBtu/hr up to 8 MMBtu/hr to be deployed in commercial industrial settings over the next two years.

SoCalGas, in an effort to decarbonize the state’s industries, is proposing the Angeles Link green hydrogen pipeline that would deliver clean, reliable, renewable energy to the Los Angeles region. The project is designed to reduce greenhouse gas emissions from electric generation, industrial processes, heavy-duty trucks, and additional hard-to-electrify sectors of Southern California’s economy.

California is enlisting the help of SoCalGas to develop a standard for hydrogen blending to integrate clean fuels at scale in the state’s natural gas system. The development of a hydrogen standard will additionally lower the cost of hydrogen by scaling up and establishing a market for the gas.

"This project offers a look at how hydrogen can play a vital role in helping industries in California start down the path to net zero through technology that allows the transition to clean fuels," said Neil Navin, SoCalGas Chief Clean Fuels Officer. "Investments in clean fuel technologies like this will be key in providing hard-to-decarbonize industries the means to reach net zero quickly and affordably."

SoCalGas has pledged its commitment and $500,000 in funding to ClearSign’s Hydrogen Ultra Low NOx burner project.

ClearSign Technologies, SoCalGas Collaborate for Hydrogen Burner Project

Technical sessions at Turbomachinery & Pump Symposia (TPS) 2023 kicked off on Tuesday, Sept. 26. Speakers from the Elliott Group presented on 

Applications and Technology for Hydrogen Compression and Pumping

. The group cycled through a series of benefits, technical challenges, and requirements for compressing hydrogen.

Marybeth McBain, Manager at Elliott Group, started the technical session with a brief description of blue, green, and pink hydrogens and the method used to produce each gas: Green hydrogen utilizes curtailed renewable electric power via electrolysis while blue and pink hydrogen require carbon sequestration and nuclear power, respectively. These iterations of hydrogen fuel can be stored for longer periods, but issues regarding cost, wear-and-tear on current pipeline assets, and embrittlement require a careful approach to hydrogen.

McBain addressed the cost of hydrogen production, as, as of now, even with tax credits, it’s expensive to produce at scale. However, she cited the initial price hikes of LNG, in which plant operators were worried LNG was too expensive. But “The industry stepped up and started looking at ways to power plants more modular to offset construction costs and to standardize equipment to lower manufacturing costs,” McBain said. After which the cost of LNG came down. She encouraged attendees to consider this when it comes to the cost of hydrogen, “and how technology can catch up and give us that cost-competitiveness,” she said.

McBain also addressed secondary concerns regarding what percentage of hydrogen would actually make a meaningful difference in carbon emissions, as using 30% hydrogen doesn’t reduce your use of natural gas by 30%; in fact, it would only reduce natural gas by 15%. She also pointed out the impact hydrogen has on carbon-steel blends (U.S. pipelines are made of several different blends) and compressor requirements—each of which must be considered when transitioning the energy economy to a hydrogen-based model.

Karl Wygant, Senior Manager at Elliott Group, tackled the challenges presented by the compression of a light gas such as hydrogen. Hydrogen compression typically encounters issues with sealing, embrittlement of materials and coating, and temperature constraints. Titanium is chosen for compression at high speeds for most gases, but hydrogen’s corrosive properties present challenges for titanium, making it unsuitable for hydrogen applications.

“Titanium is very sensitive to hydrogen embrittlement, so it’s not acceptable for hydrogen applications,” Wygant said. “What does work well is some of the aluminum series; they show good resistance to hydrogen embrittlement.”

Wygant detailed the hydrogen-resistant properties of aluminum as favorable for hydrogen compression applications, although the material encounters issues of high temperature as tip speed increases. Newer impeller designs or advanced material integration may reduce the issues encountered with hydrogen compression, such as gas corrosion or the lack of materials suited for increased tip speed. Wygant offered a series of potential solutions to the hydrogen compression dilemma, including integrally geared compressors for higher tip speed and the introduction of inter/pre-coolers to manage an increase in temperature. Aluminum may be integrated in favor of titanium with a number of coolers to regulate temperature, addressing a primary challenge in compressing hydrogen for industrial-scale operations.

Enver Karakas, Director at Elliott Group, rounded off the technical session with a detailed explanation of pumping hydrogen and ammonia. Hydrogen requires a much lower liquefaction temperature than ammonia, raising the cost of this process in comparison to the liquefaction of other gases. Handling liquid hydrogen presents a host of challenges, as the gas is highly flammable and corrosive, and the minuscule molecular size causes hydrogen to leak from the system into the atmosphere. Karakas offered a number of solutions to counteract the natural properties of hydrogen, such as a submerged motor design and material consistency to minimize stresses on the components within the system.

Liquid ammonia runs into compatibility issues with copper alloys, e.g., bronze bushing, etc. Karakas addresses ammonia leakage by introducing the concept of, although not new, magnetic couplers.

“The way we do handle this is through magnetic couplers. The whole idea is to seal the motor side from the hydraulic side, transferring the torque to the hydraulic side with a magnetic coupler to ensure that no ammonia is leaking into the motor section,” Karakas said.

The director closed the technical session with some final remarks about appropriate liquid expanders and pumps for hydrogen liquefaction. Along with considering magnetic couplers for the sealing of a system, Karakas recommended the use of cryogenic expanders to increase liquid production by 3-5%. Liquid expanders for hydrogen liquefaction achieve higher efficiency through improved cooling and energy recovery systems, counteracting the properties of hydrogen and ammonia that would typically make this process dangerous or ineffective.

Speakers from the Elliott Group presented on Applications and Technology for Hydrogen Compression and Pumping, including benefits, challenges, and solutions. 

TPS 2023: Compressing and Pumping Hydrogen - Applications and Technologies

The 2023 Turbomachinery & Pump Symposia (TPS) in Houston, TX, kicked off with a welcome address delivered by Dr. Michael Webber, professor at the University of Texas at Austin and John J. McKetta Centennial Energy Chair in Engineering. The address set the stage for this year’s display of turbomachinery and pump technology and highlighted the latest trends in the energy landscape and turbomachinery.

Dr. Michael Webber gave the keynote address on opening day of TPS 2023. Credit: Turbomachinery International 

Dr. Eric Petersen, Director of the Turbomachinery Laboratory at Texas A&M University, opened the keynote address with some helpful notes for the audience: keeping up with TPS 2023 through the designated app, attending the end-of-conference banquet, and submitting abstracts for next year’s symposia. Dr. Petersen closed his brief introduction with an outline of the Asia Turbomachinery & Pump Symposia at the Kuala Lumpur Conference Center in Kuala Lumpur, Malaysia, May 13-16, 2024. This extension of TPS is expected to garner over 2,000 attendees and exhibitors, displaying an international focus on the development of turbomachinery for the future.

Dr. Petersen handed the role of lead keynote speaker to Dr. Webber, who discussed the importance of turbomachinery in the modern world, particularly in the energy generation sector. The history of rotating technology and the predecessors to modern gas/steam turbines were laid out by Dr. Webber, citing the efficiency of continuous rotating motion in power generation as superior to back-and-forth batch power generation. He said that the world of turbomachinery, including gas turbines, will remain relevant given the stability it offers to the grid.

Dr. Petersen highlighted a few trends he sees shaping the future:

New designs that include smaller (and simultaneously, larger) turbines

Turbines that support higher temperatures

Turbines that support a wider range of fuels

Fuel flexibility that can support newer fuels such as ammonia and hydrogen as well as blends: bio-methane + hydrogen, for example

Cooling channels inside the blades (difficult, but possible)

Although the industry is buzzing with talks of hydrogen because it burns clean, challenges with handling and leakage, to name a few, complicate matters. Dr. Petersen said using a 20% hydrogen blend is fine, but higher percentages create problems. He also mentioned ammonia, which reduces emissions but increases energy usage.

Dr. Webber detailed a future in which turbomachinery integrates clean-burning fuels at ever-increasing efficiencies, separating itself from antiquated technologies incapable of fuel flexibility and carbon minimization. Gases like hydrogen, ammonia, nitrogen, and methane will go hand-in-hand with carbon sequestration to develop a power generation sector that is cleaner and more efficient than technologies of decades past.

He closed the keynote address with words of encouragement for those in the field of turbomachinery, deconstructing notions of doubt from those who believe that turbines have no place in the future of energy. Dr. Webber advised those in the crowd to keep developing turbomachinery to counter issues in modern energy generation.

The 2023 Turbomachinery & Pump Symposia in Houston, TX, kicked off with the keynote address by Dr. Michael Webber.

TPS 2023 Keynote: Turbines Will Continue to Play a Role in Power Generation, New Energy Landscape

Mitsubishi Power announced Takasago Hydrogen Park, located at Mitsubishi Heavy Industries’ (MHI) Takasago Machinery Works, began full-scale commercial operation. Electrolysis hydrogen production will bolster product reliability through hydrogen co-firing and hydrogen-operated gas turbines and expand its offerings with the introduction of hydrogen production technologies.

The validation of hydrogen-fueled equipment will be conducted at the T-Point 2 combined-cycle power plant facility using a Mitsubishi Power J-series air-cooled (JAC) gas turbine (450 MW class) and small-to-mid-sized H-25 gas turbines (40 MW class). Hydrogen produced at Takasago Hydrogen Park will be used for the validation of 30% hydrogen co-firing at T-Point 2 and is slated for completion by the end of the year. Hydrogen firing at 100% for the H-25 gas turbine will be validated in 2024.

Takasago Hydrogen Park is separated into sections based on the following hydrogen-related functions: hydrogen production, storage, and utilization. The production area is headed by HydrogenPro AS of Norway, manufacturing alkaline electrolyzers with a hydrogen production capacity of 1,100Nm3/h. Processed hydrogen will be stored in equipment with a total capacity of 39,000 Nm3.

Mitsubishi Power is developing hydrogen production technologies such as solid oxide electrolysis cells, anion exchange membrane water electrolyzers, and turquoise-hydrogen production that generates zero CO

 emissions through the pyrolysis of methane into hydrogen and solid carbon. Mitsubishi will conduct verification and validation of these technologies in sequential order. Following the development of these electrolysis technologies at the Nagasaki Carbon Neutral Park, the company intends on validating the hydrogen production of these technologies at Takasago to prepare for commercialization.

Electrolysis hydrogen production has entered full swing at the integrated hydrogen validation facility in the Hyogo Prefecture, Japan.

Mitsubishi Power’s Takasago Hydrogen Park Begins Full-Scale Production

The NextDecade Corporation’s subsidiary, Rio Grande LNG (RGLNG), is subject to a credit agreement with lenders for $356 million in senior loans to fund a portion of Phase 1 at NextDecade’s 27 million tonnes per annum (MTPA) Rio Grande LNG export facility.

A one-time advance for $356 million was granted by the lender group on Sept. 15, 2023, resulting in the reduction of commitments outstanding under RGLNG’s current term loan facilities for Phase 1 from $11.1 billion to below $10.8 billion. The loans will mature in July 2033 and will gather interest at a fixed rate of 6.72%. These loans will be ranked on equal footing to RGLNG’s existing loan facilities—a $500 million working capital facility and $700 million of 10-year senior notes granted during the final investment decision for Phase 1.

NextDecade’s secured funding adheres to the strategy outlined for Phase 1 of RGLNG: extending and staggering debt maturities, diversifying sources of capital, reducing bank capital over time to provide capacity for future LNG expansions, and minimizing exposure to interest rates. Currently, RGLNG’s fixed-rate debt and executed interest rate swaps have limited the exposure to volatile interest rates for more than 80% of the debt expected to be incurred during Phase 1 construction.

The funding will be put toward the financing of NextDecade’s LNG trains at the Rio Grande LNG export facility in Brownsville, TX. 

NextDecade’s Rio Grande LNG to Receive $356M in Senior Loans

Commonwealth LNG and EQT have structured a head of agreement (HOA) for the supply of 1 million tons per annum (MTPA) of LNG on a take-or-pay basis for 15 years. This agreement additionally covers the associated gas supply to Commonwealth LNG’s facility in Cameron, LA.

"We are very pleased to add a US producer of EQT's stature to Commonwealth's customer portfolio,” said Commonwealth LNG Founder and Executive Chairman Paul Varello. "This agreement will connect EQT's vast natural gas assets to Commonwealth's LNG facility, thus creating a value chain from wellhead to water. Accessing EQT's natural gas production, which achieved a 20 percent year-over-year reduction in Scope 1 and Scope 2 greenhouse gas emissions, supports Commonwealth's goal of achieving environmental standards."

A final investment decision for the project is expected to be delivered in Q1 2024, with the initial LNG delivery expected in 2027. The construction schedule will be fast-tracked through a modular approach and the fabrication of major components occurring offsite.

The agreed-upon terms of the HOA would take effect at the start of the facility’s commercial operation. Final terms of the agreement are pending further negotiations between parties.

One million tons per annum of LNG will be supplied by EQT for Commonwealth LNG’s facility in Cameron, LA.

Commonwealth LNG, EQT Enter Heads of Agreement for LNG Supply

Verdagy has announced the opening of new manufacturing facility in Newark, CA, containing more than 100,000 sq. ft. of space to build hydrogen electrolyzer technology.

The Silicon Valley facility will manufacture advanced water electrolyzers in vast quantity, beginning commercial operation in Q1 2024. Verdagy intends on doubling its total number of employees by next summer to support operation at the electrolyzer facility.

"We are focused on building an entire renewable hydrogen ecosystem in California to achieve our climate goals, including the crucial step of manufacturing electrolyzers," said Dee Dee Myers, Senior Advisor to Governor Newsom and Director of the Governor's Office of Business and Economic Development. "Verdagy's decision to expand its footprint here reflects California's strength in creating new markets, enabling the creation of clean-energy jobs while solving our most existential challenges with the technology of the future."

Verdagy's CA electrolyzer production facility; Image Credits: Verdagy 

Verdagy is on track to comply with the DOE’s goal of a $2/kg cost of hydrogen by 2026 through the optimization of manufacture. The development of manufacturing techniques, cost reductions, and product innovations allows Verdagy to implement a scalable manufacturing design to level the cost of hydrogen.

The opening of Verdagy’s California facility aligns with the state’s priority to develop hydrogen and receive federal funding to become a hydrogen hub, as detailed in Governor Newsom’s Hydrogen Market Development Strategy.

Last month, Verdagy partnered with Temasek and Shell Ventures to close a $73 million Series B funding round. Verdagy will utilize the funds for the launch and commercialization of its eDyanmic 20 MW electrolyzer module—the selected unit for systems at 200 MW and beyond.

"Our new Silicon Valley manufacturing facility will accelerate the production and cost reduction of our eDynamic 20 MW electrolyzer module, which is the basic building block for delivering larger, gigawatt-scale plants," said Marty Neese, Verdagy CEO.

Verdagy aims to design a facility that will become the basis for larger production factories built elsewhere, supporting the rapid manufacturing expansion goal set by the company. An existing location in Moss Landing, CA, will continue to conduct R&D and commercial pilot-plant operations to support Verdagy’s customers.

Verdagy’s facility will produce water electrolyzers at increased scale, beginning operations in early 2024.

Verdagy Opens CA Manufacturing Facility for Hydrogen Electrolyzer

Amprion GmbH, in an effort to kickstart Germany’s energy transition and replace older power assets, has awarded GE Vernova’s Grid Solutions business with a contract for 12 400 kV power transformers. These transformers will be built at GE Vernova’s grid facility in Monchengladbach, Germany.

“As utilities transition to renewable energy sources, electrical transmission grid operators continue to face increasing demand and complexity. Today’s transmission systems are expected to carry bulk power in ways they never originally were designed to accommodate,” said Philippe Piron, President and CEO of GE Vernova’s Grid Solutions business. “We are proud to support Amprion, a long-time valued GE Vernova customer, to reinforce their 400 kV electrical grid. Our power transformers will help them increase capacity and maintain stability on their network.”

GE's 400 kV power transformer; Image Credits: GE Vernova

Equivalent to more than 5,000 MVA, this order of GE power transformers is capable of supplying electricity to the 29 million people living within Amprion’s grid. The high voltage, 11,000 km-long grid stretches from Lower Saxony to the Alps, covering an area that’s responsible for one-third of Germany’s economic output. GE Vernova plans on delivering the power transformers over the course of two years, from 2025-2027.

GE Vernova’s fleet of power transformers will be replacing modules installed in the 1970s, allowing Amprion to take advantage of updated grid technology and the integration of renewables. The advanced transformers will be installed at nine substations along Amprion’s grid, joining a fleet of previously purchased GE grid products such as switchgears, gas-insulated switchgears, mechanically switched capacitors, and additional transformers. GE Vernova has been fulfilling orders from Amprion since 2003.

Amprion has awarded the supply contract to GE Vernova for the production and delivery of 12 400 kV transformers.