Publications

This paper describes the development of a general-purpose geospatial model for assessing the economic viability of hydrogen production from offshore wind power. A key feature of the model is that it uses the offshore project's location characteristics (distance to port water depth distance to gas grid injection point). Learning rates are used to predict the cost of the wind farm's components and electrolyser stack replacement. The notional wind farm used in the paper has a capacity of 510 MW. The model is implemented in a geographic information system which is used to create maps of levelised cost of hydrogen from offshore wind in Irish waters. LCOH values in 2030 spatially vary by over 50% depending on location. The geographically distributed LCOH results are summarised in a multivariate production function which is a simple and rapid tool for generating preliminary LCOH estimates based on simple site input variables.

This article presents a new technology for the generation of power and steam or other process heat with very low CO2 emissions. It is well known that cogeneration of electricity and steam is highly efficient and that amine units can be used to remove CO2 from combustion flue gas but that the amine unit consumes a significant amount of steam and power reducing the overall system efficiency. In this report the use of molten carbonate fuel cells (MCFCs) to capture CO2 from cogen units is investigated and shown to be highly efficient due to the additional power that they produce while capturing the CO2. Furthermore the MCFCs are capable of reforming methane to hydrogen simultaneous to the power production and CO2 capture. This hydrogen can either be recycled as fuel for consumption by the cogen or MCFCs or exported to an independent combustion unit as low carbon fuel thereby decarbonizing that unit as well. The efficiency of MCFCs for CO2 capture is higher than use of amines in all cases studied often by a substantial margin while at the same time the MCFCs avoid more CO2 than the amine technology. As one example the use of amines on a cogeneration unit can avoid 87.6% of CO2 but requires 4.91 MJ/kg of additional primary energy to do so. In contrast the MCFCs avoid 89.4% of CO2 but require only 1.37 MJ/kg of additional primary energy. The high thermal efficiency and hydrogen export option demonstrate the potential of this technology for widespread deployment in a low carbon energy economy.

Globally climate change fossil fuel depletion and greenhouse emissions are fundamental problems requiring massive effort from the international scientific community to be addressed and solved. Following the Clean Energy for all Europeans Package (CEP) guidelines the Italian Government has established challenging and tight objectives both on energy and climate matter to be targeted by 2030. Accordingly research activities on different topics are carried out in Italy looking at the installation of intermittent renewable energy systems (IRES) implementation of carbon capture and sequestration (CCS) on existing power plants and hydrogen technology and infrastructure penetration for accomplishing the end-users demands. The optimal integration of the above-mentioned technologies is one of the most effective weapons to address these objectives. The paper investigates different energy scenarios for meeting the Italian National Energy and Climate Plan (NECP) 2030 targets showing how the combined implementation of around +12 GW of IRES and +6 GW of electrolyzers compared to the national estimates simultaneously with the CCS of around 10 Mt of CO2 per year can reduce the CO2 emissions up to about 247 Mt/year. Thanks to the adoption of the well-established software platform EnergyPlan the integration of IRES plants CCS and hydrogen-based technologies have been explored and the most successful results for concurrently reducing the impact of industrial transport residential and energy sectors and mitigating the greenhouse emissions substantially relies on the diversifications. Results show both the technical and economic convenience of a 2030 energy scenario which implements properly hydrogen IRES and CCS penetration in the energy system meeting the NECP 2030 targets and maintaining both the over-generation of the power plants below 5 TWh and the initial capital expenditure to be sustained for this scenario to occur below +80% compared to the 2019 energy scenario.

Aerospace parts made of high strength steels such as landing gears and helicopter transmissions are often electroplated to satisfy various engineering specifications. However plated parts are occasionnaly rejected because of hydrogen embrittlement and the industry has few means of evaluating quantitatively the actual damage caused by hydrogen. In the present article we developed a novel method to measure the stress intensity threshold for hydrogen embrittlement (Kth) in industrial plating conditions. The method consists in plating side-grooved CT samples in industrial plating baths and measuring Kth with an incremental step loading methodology. We validated the method with a benchmark case known to produce embrittlement (omitted post-plating bake) and we used the method on a test case for which the level of embrittlement was unknown (delayed bake). For the benchmark case we measured a Kth of 49.0 MPa m0.5 for non-baked samples. This value is significantly lower than the fracture toughness of the unplated material which is 63.8 MPa m0.5 . We conclude that this novel combination of geometry and test method is efficient in quantifying hydrogen embrittlement of samples plated in industrial conditions. For the test case the Kth are respectively 57.9 MPa m0.5 and 58.8 MPa m0.5 for samples baked 100 h and 4 h after plating. We conclude that delaying the post-plating bake does not cause hydrogen embrittlement in the studied conditions. Using a finite element hydrogen diffusion analysis we argue that the side grooves on CT samples increase the sensitivity to hydrogen embrittlement in comparison to smooth samples. In smooth samples a zone of plane stress at the surface of the specimen shields hydrogen from penetrating to the center of the specimen a phenomenon which is alleviated with machining side grooves.

Self-sufficiency of buildings with carbon emission reduction can be obtained thanks to the introduction of Photovoltaics systems coupled with Hydrogen seasonal storage. To be self-sufficient over the year the electricity converted to hydrogen by electrolysis during the sunny season can be re-used with the help of fuel cells during the winter season. This article is dealing with the dimensioning methodology of a solar PV hydrogen-electrochemical system for self-sufficient buildings. We introduce the case study of the first private building in western Switzerland that will be equipped with solar hydrogen storage. Calculation results of the dimensioning of the PV system with storage will be presented. The life cycle assessment and the calculations of the environmental indicators GWP and CED will be introduced.

This study proposes a novel hybrid solar-gas power and hydrogen-production system which is comprised by the solar tower thermal system gas-steam turbine combined cycle and organic Rankine cycle-based hydrogen-production system. Based on the Ebsilon code the operation processes of the hybrid system are simulated. The results show that the output power and electric efficiency of the hybrid system are 103.9 MW and 41.3% and the daily hydrogen output is 62.2 kg. The operation simulation results of the hybrid system reveal that the gas-steam combined cycle and solar island can both achieve stable operations and the power generation section and hydrogen-production device can both work effectively which means the hybrid system is technically feasible. The exergy estimate results of the hybrid system show that the combustion chamber and solar receiver have the two largest exergy destructions which are 56.5 MW and 45.3 MW. That means the performances of the two components can be further improved. For the hydrogen-production system the exergy destructions of the proton exchange membrane electrolyzer turbine condenser and evaporator of the organic Rankine cycle are 0.156 MW 0.111 MW 2.338 MW and 1.891 MW and the corresponding exergy efficiencies are 51.2% 92.6% 80.7% and 79.5% respectively.

The feasibility and cost-effectiveness of hydrogen-based microgrids in facilities such as public buildings and small- and medium-sized enterprises provided by photovoltaic (PV) plants and characterized by low electric demand during weekends were investigated in this paper. Starting from the experience of the microgrid being built at the Renewable Energy Facility of Sardegna Ricerche (Italy) which among various energy production and storage systems includes a hydrogen storage system a modeling of the hydrogen-based microgrid was developed. The model was used to analyze the expected performance of the microgrid considering different load profiles and equipment sizes. Finally the microgrid cost-effectiveness was evaluated using a preliminary economic analysis. The results demonstrate that an effective design can be achieved with a PV system sized for an annual energy production 20% higher than the annual energy requested by the user and a hydrogen generator size 60% of the PV nominal power size. This configuration leads to a self-sufficiency rate of about 80% and without public grants a levelized cost of energy comparable with the cost of electricity in Italy can be achieved with a reduction of at least 25–40% of the current initial costs charged for the whole plant depending on the load profile shape.

To explore the effect of bifurcation structures on the spontaneous ignition and shock wave result from the sudden release of pressurized hydrogen. Three-way tubes with different bifurcation angles (90° 120° 150°) were used in the experiments. They are two Y-shape tubes and one T-shape tube. The photoelectric and pressure signals in the tube were recorded by the sensor. The results show that the reflected shock wave will be formed at the bifurcation. In addition the intensity and velocity of the leading shock wave will attenuate sharply when it passes through the bifurcation.The smaller bifurcation angle of tubethe smaller overpressure decay rate of shock wave at bifurcation position.The smaller the bifurcation angle of tubes the weaker the reflected shock wave transmitted downstream and the greater attenuation of shock wave intensity. Experimental results have reference value for the safety of hydrogen storage at high-pressure and are helpful to understand the influence of different tube structures on spontaneous ignition when hydrogen is transported at high pressure.

The independent cross-party report highlights a ‘sensible middle ground’ in the renewables debate and calls for more effort in building cross-party consensus. It finds that the UK has only just begun to harness low carbon renewable resources bigger than North Sea oil and gas and argues that the Government could do more to narrow the scope of debate about the technology mix beyond 2020. It argues that it should work with industry and academia first to establish ‘low regrets’ levels of technology deployment and second to ensure that policies are in place to incentivise investments such as supply chain investment needed to deliver these low regrets actions.

This approach would help provide the longer term clarity that could secure supply chain investments giving the UK a head-start in the global race. The report finds that these investments could be missed delayed or more expensive if there is insufficient confidence about long term demand for key technologies such as offshore wind. Work by Government to help incentivise these investments would increase the likelihood that technology cost reductions are achieved and help mitigate against high costs if new nuclear or carbon capture and storage development fail or are delayed.

On affordability the report finds that there are ‘hidden’ benefits that the UK could see from investing more in renewables through electricity bills between now and 2020. These include: avoiding bill increases driven by fossil fuels; making electricity bills more predictable; and providing an economic boost. The extra money paid to support renewables and other low carbon generation such as nuclear power could be more than offset by energy efficiency savings although Government needs to do more to show how these savings will arise.

On sustainability the report tackles myths about the carbon emitted in manufacturing renewable technologies or in backing up varying technologies such as wind solar wave and tidal. It finds that even when considering these factors renewables are still amongst the most low carbon options. The report also looks at the sustainability of electricity from biomass. Bioenergy overall could provide up to ten per cent of energy and reduce the cost of cutting carbon by £44 billion per year in 2050. The Government’s new biomass policies are a pragmatic response to concerns about the sustainability of biomass power which balances protecting the environment building public confidence and enabling the sector to grow.

On security of supply the inquiry argues that debate should focus on the whole electricity system and that individual technologies should be considered in the context of how they add to or reduce system risks. Considered like this renewables reduce some risks such as fuel supply risks which caused concern last winter and add to others such as system balancing risks. System balancing risks from varying renewables (wind solar wave and tidal technologies) are manageable using a number of existing and developing technologies.

The independent report chaired by former Energy Minister Charles Hendry MP and Shadow Energy Minister Baroness Worthington was compiled between May and September 2013 and was sponsored by Siemens and DONG Energy. It is part of a year-long independent and cross party inquiry into the UK power sector the Future Electricity Series sponsored by the Institution of Gas Engineers and Managers.

Link to Launch Video

The application of appropriate procedures in the downstream gas industry (defined as any works downstream of the emergency control value) is critical in protecting consumers of gas both domestic and commercial. The two primary standard setting bodies for the downstream gas industry are the British Standard Institution (BSI) and the Institution of Gas Engineers and Managers (IGEM). To ensure only competent engineers carry out works on a gas installation all gas businesses or selfemployed persons must become a member of Gas Safe Register as stipulated by the Gas Safety (Installation and Use) Regulations 1998 1 and each gas operative shall be included on the register and hold a valid license card that covers the areas of gas work they undertake. Membership of the Gas Safe Register is contingent upon demonstration of competency the recognised competency assessments are based on the relevant BSI and IGEM standards. Therefore the primary source of a gas operative’s competency to work on natural gas installations are the associated BSI and IGEM natural gas downstream standards.<br/>Investigation was undertaken to understand the potential implications of introducing 20 mol% hydrogen (H2) within natural gas supplies on the ability of gas operatives to competently carry out works. This investigation took the form of identifying all BSI and IGEM standards that could be applied on natural gas installations and reviewing them within the context of the known effects of introducing a 20 mol% H2 blend. Following review a series of technical questions were generated and responded to by the Health and Safety Executive Science Division. The responses provided were then reviewed and if considered necessary challenged to provide further information. The procedural review was led by Blue Flame Associates a body deemed sufficiently competent in downstream standards training certification and investigation. The report was subsequently reviewed by industry and feedback received. The industry comments were reviewed by the Project Team and where considered necessary the report was updated.