TECHNICAL PROGRAMME | Energy Infrastructure – Future Pathways
Hydrogen Transportation
Forum 10 | Hall 9 - Technical Programme 2
14
October
10:00
11:30
UTC+3
Hydrogen is an energy source to become the key for the carbon neutral. Since its utilisation and application are expanding out not only as fuel but also as a raw material, hydrogen is expected to be utilised in the wide industrial fields. For promoting the utilisation of hydrogen, construction of the hydrogen supply chain is indispensable, and in recent years the development of marine transportation technology to enable a long-distance and mass transit, various techniques about pipelines and trailers delivering hydrogen to the demand place, and technologies for storage of a large quantity of hydrogen are attracting attention. This forum is focused on the current situation of technologies and the infrastructure necessary for hydrogen transportation and future challenges.
Over the last decade, the deployment of nonmetallic pipes at Saudi Aramco has been exponential and reached an unprecedented level. Reinforced Thermoplastic pipes (RTP) are slowly becoming the product of choice for surface transport of pressurized oil, gas and water systems. Realizing the tremendous benefits that can be realized from lifecyle costs savings, Saudi Aramco has been playing a catalyst role in the RTP market to promote the emergence of new products and new applications. Owing primarily to their corrosion-free nature and competitive lifecycle costs, RTP are now gaining great deal of attention in the development of green energy infrastructure, particualry for hydrogen transport.
Polymeric materials are permeable to gases particularly at high temperature and pressure. The use of RTP to transport pressurized hydrogen raises the natural concern over their ability to limit hydrogen leakage through permeation. In the absence of an industry standard for qualification for RTP in hydrogen service, pipe suppliers draw on the specifications in API 15S where permeation testing is carried out at coupon level (and seldom at pipe level) to assess the permeation barrier performance of the pipe materials. The present work will detail some recent findings in hydrogen permeation testing of different RTP products at different scales. Coupon-level testing was carried out for a combination of liner and pipe wall materials to compare to the barrier performance of different liner materials but also the contribution of the liner to the overall permeation level. Full scale pipe testing was also carried out to compare to coupon-level data and highlight some of the limitations in predicting pipe level behavior from coupon-level testing. The data presented in this work are a first step towards the development of low permeation RTP for hydrogen transport.
Polymeric materials are permeable to gases particularly at high temperature and pressure. The use of RTP to transport pressurized hydrogen raises the natural concern over their ability to limit hydrogen leakage through permeation. In the absence of an industry standard for qualification for RTP in hydrogen service, pipe suppliers draw on the specifications in API 15S where permeation testing is carried out at coupon level (and seldom at pipe level) to assess the permeation barrier performance of the pipe materials. The present work will detail some recent findings in hydrogen permeation testing of different RTP products at different scales. Coupon-level testing was carried out for a combination of liner and pipe wall materials to compare to the barrier performance of different liner materials but also the contribution of the liner to the overall permeation level. Full scale pipe testing was also carried out to compare to coupon-level data and highlight some of the limitations in predicting pipe level behavior from coupon-level testing. The data presented in this work are a first step towards the development of low permeation RTP for hydrogen transport.
In the context of the energy transition, hydrogen is poised to become a key energy source for power generation, heat generation, and mobility. For large-scale hydrogen storage, underground techniques offer several advantages over surface storage, including reduced environmental footprint, enhanced safety, and cost-effectiveness.
Underground storage of natural gas has been practiced for over a century, with more than 3,000 caverns/porous reservoirs in the world. Similarly, hydrogen storage in underground salt caverns has been used for industrial processes for several decades. In preparation for the energy transition, several pilot projects for hydrogen underground storage in salt, depleted fields, and saline aquifers have been developed.
There are five main techniques for underground hydrogen storage:
The capital expenditure (CAPEX) for these techniques varies significantly based on geology, storage capacities, and operational requirements. For example, storage solutions based on porous reservoirs have an estimated cost of about 20€/kg, while salt caverns technology costs around 35€/kg. Storing gaseous hydrogen in mined, lined rock caverns is more challenging to assess, with costs ranging from 250€/kg to 500€/kg. There is no available data on the CAPEX for storing liquid hydrogen in mined, lined rock caverns, but costs are expected to be higher. For comparison, surface storage CAPEX varies between 1,000 and 2,000€/kg.
In conclusion, underground hydrogen storage has a history of over 50 years, and ongoing research and development efforts are necessary to mitigate risks and expand the solution portfolio.
Underground storage of natural gas has been practiced for over a century, with more than 3,000 caverns/porous reservoirs in the world. Similarly, hydrogen storage in underground salt caverns has been used for industrial processes for several decades. In preparation for the energy transition, several pilot projects for hydrogen underground storage in salt, depleted fields, and saline aquifers have been developed.
There are five main techniques for underground hydrogen storage:
- Salt Caverns: The most mature method, involving the creation of caverns by injecting freshwater into a geological layer of salt. The salt acts as a natural sealant, and this technique has been used for over 50 years.
- Porous Rocks: Utilizing naturally porous rocks covered by impermeable rock to create a geological trap. This method offers high storage capacities and has been used in the past for hydrogen mixed with methane and carbon dioxide.
- Hard Rock Caverns for Liquid Organic Hydrogen Carriers (LOHC): Constructing caverns in hard rock to store hydrogen converted into a liquid carrier, such as ammonia. Contact with water is to be avoided for some of these LOHC. This may require the installation of a liner.
- Direct Injection of Gaseous Hydrogen into lined rock caverns: Involves injecting gaseous hydrogen into a rock cavern, with high pressure necessitating a liner. This technique is being actively developed in Europe.
- Direct Injection of liquid hydrogen into lined rock caverns: Involves injecting liquid hydrogen into a lined rock cavern using cryogenic techniques. This method is still in the early stages of development.
The capital expenditure (CAPEX) for these techniques varies significantly based on geology, storage capacities, and operational requirements. For example, storage solutions based on porous reservoirs have an estimated cost of about 20€/kg, while salt caverns technology costs around 35€/kg. Storing gaseous hydrogen in mined, lined rock caverns is more challenging to assess, with costs ranging from 250€/kg to 500€/kg. There is no available data on the CAPEX for storing liquid hydrogen in mined, lined rock caverns, but costs are expected to be higher. For comparison, surface storage CAPEX varies between 1,000 and 2,000€/kg.
In conclusion, underground hydrogen storage has a history of over 50 years, and ongoing research and development efforts are necessary to mitigate risks and expand the solution portfolio.
Safe and efficient storage and transportation are preconditions for the large scale development of hydrogen energy. For scenarios with long distances and large transportation volumes, pipeline hydrogen transportation is the best choice. Due to the significant differences in structure and properties between hydrogen and natural gas, there is a lack of data support for directly using HDPE gas pipelines to transport hydrogen, and there are certain risks. This paper studies the microstructure of special materials for gas pipelines and the hydrogen permeability, designs and develops a set of test device that uses hydrogen as the medium and can evaluate the long-term hydrostatic pressure strength of HDPE materials according to ISO 9080. The YGH 041T special material for gas pipelines produced by Sinopec is selected for the test to explore the influence of hydrogen on the long-term strength of HDPE materials.
In this paper, by choosing a four parameter model, the relationship among test temperature, test pressure, and failure time in a hydrogen environment is discussed. The obtained data are fitted by multiple linear regression to determine the long-term hydrostatic pressure strength of YGH 041T in a hydrogen environment. The test results show that: (1) Hydrogen permeability is related to the crystallinity of the material. The higher the crystallinity, the lower the permeability. Under normal temperature and standard atmospheric pressure, the hydrogen permeation amount per unit thickness of PE100 grade material is only 10-14(cm³/(cm²d Pa)); (2) Under the same test temperature and test pressure conditions, the failure time of the test sample is affected by the test medium. The failure time with water as the medium is longer than that with hydrogen, and the higher the test temperature or test pressure, the more obvious the difference in failure time; (3) In the tests with hydrogen as the medium, at three temperature conditions of 20°C, 60°C, and 80°C, there is no inflection point within 8760h, and the failure mode of all samples is ductile failure; (4) Through multiple linear regression fitting of all data, the 50 year long-term hydrostatic pressure strength σ(hydrogen) is lower than σ(water), but the extrapolation curve of hydrogen is still above the PE100 standard curve.
In this paper, by choosing a four parameter model, the relationship among test temperature, test pressure, and failure time in a hydrogen environment is discussed. The obtained data are fitted by multiple linear regression to determine the long-term hydrostatic pressure strength of YGH 041T in a hydrogen environment. The test results show that: (1) Hydrogen permeability is related to the crystallinity of the material. The higher the crystallinity, the lower the permeability. Under normal temperature and standard atmospheric pressure, the hydrogen permeation amount per unit thickness of PE100 grade material is only 10-14(cm³/(cm²d Pa)); (2) Under the same test temperature and test pressure conditions, the failure time of the test sample is affected by the test medium. The failure time with water as the medium is longer than that with hydrogen, and the higher the test temperature or test pressure, the more obvious the difference in failure time; (3) In the tests with hydrogen as the medium, at three temperature conditions of 20°C, 60°C, and 80°C, there is no inflection point within 8760h, and the failure mode of all samples is ductile failure; (4) Through multiple linear regression fitting of all data, the 50 year long-term hydrostatic pressure strength σ(hydrogen) is lower than σ(water), but the extrapolation curve of hydrogen is still above the PE100 standard curve.
The Global energy transition hinges on hydrogen, but the inconsistent geographical distribution of renewable energy sources presents a major hurdle to the development of the hydrogen economy. Challenges persist in low-carbon hydrogen storage and transportation. Currently proposed methods like liquefaction and ammonia come with substantial costs and safety concerns, necessitating a disruptive solution. Enter the Honeywell Liquid Organic Hydrogen Carrier (LOHC) Solution, a game-changing approach poised to revolutionize large-scale hydrogen transport.
Honeywell's LOHC technology stands out for its immediate readiness, leveraging existing petroleum infrastructure and decades of proven expertise in safe catalysts and technologies. Recent cost analyses indicate competitive pricing, with LOHC shipping costs comparable to ammonia, but with potential for the Honeywell LOHC solution to add further improvement through design enhancements, energy efficiency measures, and repurposing of existing refinery units.
The Middle East is ideally positioned to develop world-scale low-carbon hydrogen production facilities, thanks to its abundant solar and wind resources and well-established energy infrastructure. The region's strategic location also facilitates hydrogen export to both Europe and Asia. Leveraging its extensive experience in oil refining, the Middle East is well-suited to utilize LOHC for hydrogen transport, seamlessly integrating this new energy vector into its existing petroleum infrastructure.
This presentation will delve into the process and catalyst technologies powering the Honeywell LOHC solution, the compelling economic aspects, and the momentum behind its commercial adoption as seen in the recently announced projects.
Honeywell's LOHC technology stands out for its immediate readiness, leveraging existing petroleum infrastructure and decades of proven expertise in safe catalysts and technologies. Recent cost analyses indicate competitive pricing, with LOHC shipping costs comparable to ammonia, but with potential for the Honeywell LOHC solution to add further improvement through design enhancements, energy efficiency measures, and repurposing of existing refinery units.
The Middle East is ideally positioned to develop world-scale low-carbon hydrogen production facilities, thanks to its abundant solar and wind resources and well-established energy infrastructure. The region's strategic location also facilitates hydrogen export to both Europe and Asia. Leveraging its extensive experience in oil refining, the Middle East is well-suited to utilize LOHC for hydrogen transport, seamlessly integrating this new energy vector into its existing petroleum infrastructure.
This presentation will delve into the process and catalyst technologies powering the Honeywell LOHC solution, the compelling economic aspects, and the momentum behind its commercial adoption as seen in the recently announced projects.
Abdullah Faisal Al Marshed
Chair
Professor
Kuwait Institute for Scientific Research (KISR)
Kuwait
ShaoHua Dong
Vice Chair
Director of the Pipeline Technology and Safety Research Center
China University of Petroleum (Beijing)
China
In the context of the energy transition, hydrogen is poised to become a key energy source for power generation, heat generation, and mobility. For large-scale hydrogen storage, underground techniques offer several advantages over surface storage, including reduced environmental footprint, enhanced safety, and cost-effectiveness.
Underground storage of natural gas has been practiced for over a century, with more than 3,000 caverns/porous reservoirs in the world. Similarly, hydrogen storage in underground salt caverns has been used for industrial processes for several decades. In preparation for the energy transition, several pilot projects for hydrogen underground storage in salt, depleted fields, and saline aquifers have been developed.
There are five main techniques for underground hydrogen storage:
The capital expenditure (CAPEX) for these techniques varies significantly based on geology, storage capacities, and operational requirements. For example, storage solutions based on porous reservoirs have an estimated cost of about 20€/kg, while salt caverns technology costs around 35€/kg. Storing gaseous hydrogen in mined, lined rock caverns is more challenging to assess, with costs ranging from 250€/kg to 500€/kg. There is no available data on the CAPEX for storing liquid hydrogen in mined, lined rock caverns, but costs are expected to be higher. For comparison, surface storage CAPEX varies between 1,000 and 2,000€/kg.
In conclusion, underground hydrogen storage has a history of over 50 years, and ongoing research and development efforts are necessary to mitigate risks and expand the solution portfolio.
Underground storage of natural gas has been practiced for over a century, with more than 3,000 caverns/porous reservoirs in the world. Similarly, hydrogen storage in underground salt caverns has been used for industrial processes for several decades. In preparation for the energy transition, several pilot projects for hydrogen underground storage in salt, depleted fields, and saline aquifers have been developed.
There are five main techniques for underground hydrogen storage:
- Salt Caverns: The most mature method, involving the creation of caverns by injecting freshwater into a geological layer of salt. The salt acts as a natural sealant, and this technique has been used for over 50 years.
- Porous Rocks: Utilizing naturally porous rocks covered by impermeable rock to create a geological trap. This method offers high storage capacities and has been used in the past for hydrogen mixed with methane and carbon dioxide.
- Hard Rock Caverns for Liquid Organic Hydrogen Carriers (LOHC): Constructing caverns in hard rock to store hydrogen converted into a liquid carrier, such as ammonia. Contact with water is to be avoided for some of these LOHC. This may require the installation of a liner.
- Direct Injection of Gaseous Hydrogen into lined rock caverns: Involves injecting gaseous hydrogen into a rock cavern, with high pressure necessitating a liner. This technique is being actively developed in Europe.
- Direct Injection of liquid hydrogen into lined rock caverns: Involves injecting liquid hydrogen into a lined rock cavern using cryogenic techniques. This method is still in the early stages of development.
The capital expenditure (CAPEX) for these techniques varies significantly based on geology, storage capacities, and operational requirements. For example, storage solutions based on porous reservoirs have an estimated cost of about 20€/kg, while salt caverns technology costs around 35€/kg. Storing gaseous hydrogen in mined, lined rock caverns is more challenging to assess, with costs ranging from 250€/kg to 500€/kg. There is no available data on the CAPEX for storing liquid hydrogen in mined, lined rock caverns, but costs are expected to be higher. For comparison, surface storage CAPEX varies between 1,000 and 2,000€/kg.
In conclusion, underground hydrogen storage has a history of over 50 years, and ongoing research and development efforts are necessary to mitigate risks and expand the solution portfolio.
Valentina Di Mauro
Speaker
Global Director Business Development LOHC
Honeywell UOP
United Kingdom
The Global energy transition hinges on hydrogen, but the inconsistent geographical distribution of renewable energy sources presents a major hurdle to the development of the hydrogen economy. Challenges persist in low-carbon hydrogen storage and transportation. Currently proposed methods like liquefaction and ammonia come with substantial costs and safety concerns, necessitating a disruptive solution. Enter the Honeywell Liquid Organic Hydrogen Carrier (LOHC) Solution, a game-changing approach poised to revolutionize large-scale hydrogen transport.
Honeywell's LOHC technology stands out for its immediate readiness, leveraging existing petroleum infrastructure and decades of proven expertise in safe catalysts and technologies. Recent cost analyses indicate competitive pricing, with LOHC shipping costs comparable to ammonia, but with potential for the Honeywell LOHC solution to add further improvement through design enhancements, energy efficiency measures, and repurposing of existing refinery units.
The Middle East is ideally positioned to develop world-scale low-carbon hydrogen production facilities, thanks to its abundant solar and wind resources and well-established energy infrastructure. The region's strategic location also facilitates hydrogen export to both Europe and Asia. Leveraging its extensive experience in oil refining, the Middle East is well-suited to utilize LOHC for hydrogen transport, seamlessly integrating this new energy vector into its existing petroleum infrastructure.
This presentation will delve into the process and catalyst technologies powering the Honeywell LOHC solution, the compelling economic aspects, and the momentum behind its commercial adoption as seen in the recently announced projects.
Honeywell's LOHC technology stands out for its immediate readiness, leveraging existing petroleum infrastructure and decades of proven expertise in safe catalysts and technologies. Recent cost analyses indicate competitive pricing, with LOHC shipping costs comparable to ammonia, but with potential for the Honeywell LOHC solution to add further improvement through design enhancements, energy efficiency measures, and repurposing of existing refinery units.
The Middle East is ideally positioned to develop world-scale low-carbon hydrogen production facilities, thanks to its abundant solar and wind resources and well-established energy infrastructure. The region's strategic location also facilitates hydrogen export to both Europe and Asia. Leveraging its extensive experience in oil refining, the Middle East is well-suited to utilize LOHC for hydrogen transport, seamlessly integrating this new energy vector into its existing petroleum infrastructure.
This presentation will delve into the process and catalyst technologies powering the Honeywell LOHC solution, the compelling economic aspects, and the momentum behind its commercial adoption as seen in the recently announced projects.
Over the last decade, the deployment of nonmetallic pipes at Saudi Aramco has been exponential and reached an unprecedented level. Reinforced Thermoplastic pipes (RTP) are slowly becoming the product of choice for surface transport of pressurized oil, gas and water systems. Realizing the tremendous benefits that can be realized from lifecyle costs savings, Saudi Aramco has been playing a catalyst role in the RTP market to promote the emergence of new products and new applications. Owing primarily to their corrosion-free nature and competitive lifecycle costs, RTP are now gaining great deal of attention in the development of green energy infrastructure, particualry for hydrogen transport.
Polymeric materials are permeable to gases particularly at high temperature and pressure. The use of RTP to transport pressurized hydrogen raises the natural concern over their ability to limit hydrogen leakage through permeation. In the absence of an industry standard for qualification for RTP in hydrogen service, pipe suppliers draw on the specifications in API 15S where permeation testing is carried out at coupon level (and seldom at pipe level) to assess the permeation barrier performance of the pipe materials. The present work will detail some recent findings in hydrogen permeation testing of different RTP products at different scales. Coupon-level testing was carried out for a combination of liner and pipe wall materials to compare to the barrier performance of different liner materials but also the contribution of the liner to the overall permeation level. Full scale pipe testing was also carried out to compare to coupon-level data and highlight some of the limitations in predicting pipe level behavior from coupon-level testing. The data presented in this work are a first step towards the development of low permeation RTP for hydrogen transport.
Polymeric materials are permeable to gases particularly at high temperature and pressure. The use of RTP to transport pressurized hydrogen raises the natural concern over their ability to limit hydrogen leakage through permeation. In the absence of an industry standard for qualification for RTP in hydrogen service, pipe suppliers draw on the specifications in API 15S where permeation testing is carried out at coupon level (and seldom at pipe level) to assess the permeation barrier performance of the pipe materials. The present work will detail some recent findings in hydrogen permeation testing of different RTP products at different scales. Coupon-level testing was carried out for a combination of liner and pipe wall materials to compare to the barrier performance of different liner materials but also the contribution of the liner to the overall permeation level. Full scale pipe testing was also carried out to compare to coupon-level data and highlight some of the limitations in predicting pipe level behavior from coupon-level testing. The data presented in this work are a first step towards the development of low permeation RTP for hydrogen transport.
Zhang Wei
Speaker
Senior Engineer
Sinopec (Beijing) Research Institute of Chemical Industry Co. Ltd
China
Safe and efficient storage and transportation are preconditions for the large scale development of hydrogen energy. For scenarios with long distances and large transportation volumes, pipeline hydrogen transportation is the best choice. Due to the significant differences in structure and properties between hydrogen and natural gas, there is a lack of data support for directly using HDPE gas pipelines to transport hydrogen, and there are certain risks. This paper studies the microstructure of special materials for gas pipelines and the hydrogen permeability, designs and develops a set of test device that uses hydrogen as the medium and can evaluate the long-term hydrostatic pressure strength of HDPE materials according to ISO 9080. The YGH 041T special material for gas pipelines produced by Sinopec is selected for the test to explore the influence of hydrogen on the long-term strength of HDPE materials.
In this paper, by choosing a four parameter model, the relationship among test temperature, test pressure, and failure time in a hydrogen environment is discussed. The obtained data are fitted by multiple linear regression to determine the long-term hydrostatic pressure strength of YGH 041T in a hydrogen environment. The test results show that: (1) Hydrogen permeability is related to the crystallinity of the material. The higher the crystallinity, the lower the permeability. Under normal temperature and standard atmospheric pressure, the hydrogen permeation amount per unit thickness of PE100 grade material is only 10-14(cm³/(cm²d Pa)); (2) Under the same test temperature and test pressure conditions, the failure time of the test sample is affected by the test medium. The failure time with water as the medium is longer than that with hydrogen, and the higher the test temperature or test pressure, the more obvious the difference in failure time; (3) In the tests with hydrogen as the medium, at three temperature conditions of 20°C, 60°C, and 80°C, there is no inflection point within 8760h, and the failure mode of all samples is ductile failure; (4) Through multiple linear regression fitting of all data, the 50 year long-term hydrostatic pressure strength σ(hydrogen) is lower than σ(water), but the extrapolation curve of hydrogen is still above the PE100 standard curve.
In this paper, by choosing a four parameter model, the relationship among test temperature, test pressure, and failure time in a hydrogen environment is discussed. The obtained data are fitted by multiple linear regression to determine the long-term hydrostatic pressure strength of YGH 041T in a hydrogen environment. The test results show that: (1) Hydrogen permeability is related to the crystallinity of the material. The higher the crystallinity, the lower the permeability. Under normal temperature and standard atmospheric pressure, the hydrogen permeation amount per unit thickness of PE100 grade material is only 10-14(cm³/(cm²d Pa)); (2) Under the same test temperature and test pressure conditions, the failure time of the test sample is affected by the test medium. The failure time with water as the medium is longer than that with hydrogen, and the higher the test temperature or test pressure, the more obvious the difference in failure time; (3) In the tests with hydrogen as the medium, at three temperature conditions of 20°C, 60°C, and 80°C, there is no inflection point within 8760h, and the failure mode of all samples is ductile failure; (4) Through multiple linear regression fitting of all data, the 50 year long-term hydrostatic pressure strength σ(hydrogen) is lower than σ(water), but the extrapolation curve of hydrogen is still above the PE100 standard curve.
