Clean Hydrogen JU - SRIA Key Performance Indicators (KPIs)

Notes:

(General for system): Standard boundary conditions that apply to all electrolytic system KPIs: input of AC power and tap water; output of hydrogen meeting ISO 14687-2 at a pressure of 30 bar and hydrogen purity 5. Correction factors may be applied if actual boundary conditions are different.

All KPIs are interdependent and should be met simultaneously.

KPI-1: Electrical energy demand at nominal hydrogen production rate of the system at standard boundary conditions, including energy required for cooling.

KPI-2: Capital cost are based on 100 MW production volume for a single company and on a 10-year system lifetime running in steady state operation, whereby end of life is defined as 10% increase in energy required for production of hydrogen. Stack replacements are not included in capital cost. Cost are for installation on a pre-prepared site (fundament/building and necessary connections are available). Transformers and rectifiers are to be included in the capital cost.

KPI-3: Operation and maintenance cost averaged over the first 10 years of the system. Potential stack replacements are not included in O&M cost. Electricity costs are not included in O&M cost.

KPI-4: Time required to reach nominal capacity in terms of hydrogen production rate when starting the device from hot idle (warm standby mode - system already at operating temperature and pressure).

KPI-5: Time required to reach nominal capacity in terms of hydrogen production rate when starting the device from cold standby mode.

KPI-6: Stack degradation defined as percentage efficiency loss when run at nominal capacity. For example, 0.125%/1,000h results in 10% increase in energy consumption over a 10-year lifespan with 8,000 operating hours per year.

KPI-7: Mean current density of the electrolysis cell running at operating temperature and pressure and nominal hydrogen production rate of the stack. Measured in Ampere per square centimeter (A/cm²).

KPI-8: The critical raw material considered here is ruthenium for the cathode (mostly as RuO₂)

Notes:

General for system: Standard boundary conditions that apply to all system KPIs: input of AC power and tap water; output of hydrogen meeting ISO 14687-2 at a pressure of 30 bar and hydrogen purity 5. Correction factors may be applied if actual boundary conditions are different.

All KPIs are interdependent and should be met simultaneously.

(KPI-1) to (KPI-4): Similar conditions as for alkaline technology (Table 2).

KPI-2: CAPEX is based on the assumption of 100 MW manufacturing for a single company, as per current definition.

KPI-5: time required to reach nominal capacity in terms of hydrogen production rate when starting the device from cold start from -20°C.

KPI-6: Stack degradation defined as percentage efficiency loss when run at nominal capacity. For example, 0.125%/1,000h results in 10% increase in energy consumption over a 10-year lifespan with 8,000 operating hours per year.

Degradation and energy consumption KPIs are interdependent and should to be met simultaneously.

KPI-7: Mean current density of the electrolysis cell running at operating temperature and pressure and nominal hydrogen production rate of the stack.

KPI-8: These are mainly iridium and ruthenium as the anode catalyst (SOA 2.0 mg/cm²) and platinum as the cathode catalyst (SOA 0.5 mg/cm²)

Notes:

(General for system): Standard boundary conditions that apply to all system KPIs: input of AC power and tap water; output of hydrogen meeting ISO 14687-2 at atmospheric pressure and hydrogen purity 5. Correction factors may be applied if actual boundary conditions are different.

All KPIs are interdependent and should be met simultaneously, except for reversible parameters which concern only reversible systems.

KPI-1: Electrical energy demand similar as for alkaline technology (Table 2). Heat demand is the heat absorption of the system at nominal capacity (mostly provided by steam).

KPI-2: Capital cost are based on 100 MW production volume for a single company and on a 10-year system lifetime running in steady state operation, whereby end of life is defined as 10% increase in energy required for production of hydrogen. Stack replacements are not included in capital cost. Cost are for installation on a pre-prepared site (fundament/building and necessary connections are available). Transformers and rectifiers are to be included in the capital cost.

KPI-3: Operation and maintenance cost averaged over the first 10 years of the system. Potential stack replacements are included in O&M cost. Electricity costs are not included in O&M cost.

KPI-4: Time required to reach nominal capacity in terms of hydrogen production rate when starting the device from hot idle (warm standby mode - system already at operating temperature and pressure).

KPI-5: Time required to reach nominal capacity in terms of hydrogen production rate when starting the device from cold standby mode.

KPI-6: Degradation under thermo-neutral conditions (@UTN) in percent loss of production rate (hydrogen power output) at constant efficiency. Note this is a different definition as for low temperature electrolysis, reflecting the difference in technology. Testing time should be a minimum of 2000 h.

KPI-7: Mean current density of the electrolysis cell running at operating temperature and pressure and nominal hydrogen production rate of the stack.

KPI8: Roundtrip electrical efficiency is defined as energy discharged measured on the primary point of connection (POC) divided by the electric energy absorbed, measured on all the POC (primary and auxiliary), over one electrical energy storage system standard charging/discharging cycle in specified operating conditions.

KPI-9: Reversible capacity is defined as ratio of the nominal rated power in fuel cell mode to the electric power at nominal capacity in electrolyser mode of the SOEL system

Notes:

General for system: Standard boundary conditions that apply to all system KPIs: input of AC power and tap water; output of hydrogen meeting ISO 14687-2 at atmospheric pressure and hydrogen purity 5. Correction factors may be applied if actual boundary conditions are different.

(KPI-1) to (KPI-7): Similar conditions as for alkaline technology (Table 2) and applying ISO 14687-2.

KPI-7: Only data from scientific papers available, target values for KOH based electrolyte < 1.0 %mol.

KPI-8: This is mainly IrOx as the anode catalyst and Pt/C as the cathode catalyst

Notes:

KPI-1: Ramp duration (time) to reach full power

KPI-2: Stability in constant power sections,

KPI-3: The ramp precision is the percentage of data points outside of the desired range, linked to KPI 2, both KPIs are closely related because they describe the precision of power control of electrolyser systems

KPI-4: Percentage of operations following the ramping protocols that were successfully completed as described. linked to KPI 1 to 3. It is the success rate of following the protocols / procedures measured using KPIs 1 to 3

Notes:

KPI-1: The energy use here considers both heat and electricity. (N.B.: The electricity consumption is reported as an equivalent heat consumption considering a reference thermal-to-electricity conversion efficiency of 45%).  The system energy use is based on the efficiency value of 51.7% related to a plant on Anaerobic Digestion (AD) based on steam reforming conversion process. It is considering the LHV as calorific value of the Hydrogen. The best steam reforming case with AD biogas (58% of CH₄) and a plant size is 100 kgH₂/day, including Pressure Swing Adsorption (PSA) system.

KPI-2: Capital cost of the production plant per nominal daily production (€/(kg/d)). Capital cost should include all the cost related to all the equipment necessary for the normal operation of the plant. Plant size is 100 kgH₂/day. Output of hydrogen meeting ISO 14687-2 at a pressure of 20 bar and hydrogen purity 5.0. Clean biogas without H₂S is assumed.

KPI-3: The value includes the expenditures for biogas and water, electrical and heat consumption, maintenance, spare parts, catalyst, adsorbent material and desulphurisation

Notes:

KPI-1: System carbon yield: Kg H₂ obtained from biomass fed to the reactor expressed in Kg COD (Chemical Oxygen Demand). Max theoretically obtainable is 0.041 KgH₂/kg.

KPI-2: kg H₂ produced per day per m³ of reactor volume

KPI-3: Reactor size measured in m³ of fermenter

KP-4: Capital cost of plant divided by the nominal hydrogen production. Capital cost includes all the cost related to all the equipment necessary for the normal operation of the plant. Based on an estimated production of 949,200 m³ H₂ per year, therefore the capacity of the reference plant is 232 kg H₂/d.

KPI-5: Operation and maintenance cost averaged over the first 10 years of the system. Routine maintenance and "wear and tear" (rotating parts, cleaning of equipment...) considering a lifespan of 20 years. Costs such as water use, personnel and chemicals are included. The fermenter size is assumed as 200 m³, treating 100 tons of food waste per day 

Notes:

* Boundary conditions: location with direct normal irradiation (DNI) of 2500 kWh/m²/year. Output of hydrogen meeting ISO 14687-2 at a pressure of 15 bar and hydrogen purity 5.0.

KPI-2: System capital cost for a specific hydrogen production rate based on kg of hydrogen generated per day at a given cumulative DNI per year. Capital cost should include all the cost related to all the equipment necessary for the normal operation of the plant.

KPI-3: O&M cost averaged over the first 10 years of the system. Routine maintenance and "wear and tear" (rotating parts, cleaning of equipment, etc). Electricity costs for operation of auxiliary units included. System level losses such as heliostat collector area losses, replacement parts, operation, and maintenance are included in the cost calculations

 Notes:

Boundary Conditions: the specific average gas composition considered for a typical product gas is: 40% H₂, 24% CO, 23 % CO2, 10% CH₄ and 3% C₂H₄. Output of hydrogen at a purity of 99.97% at 10 bar.

KPI-1: Ratio between the kg of H₂ produced from the gasification process and the kg of C present in the syngas product.

KPI-2: CAPEX considered includes investment costs for the chemical plant of a double bed fluidised gasifier. The value also includes the plant start-up expenses as 10% of the investment cost. Capital cost should include all the cost related to all the equipment necessary for the normal operation of the plant.

KPI-3: Operation and maintenance cost averaged over the first 10 years of the system. Routine maintenance and "wear and tear" (rotating parts, cleaning of equipment...) was estimated considering a plant life of 20 years. Feedstock and electricity costs are not included in O&M cost

Notes:

Depleted gas field: pressure hydrogen storage in a depleted gas field, around 1,000 and 2,000 meters below the ground

Salt cavern: underground hydrogen storage in a located between 1,000 and 2,000 meters below the ground level, pure H₂ considered (100% H₂)

Aboveground storage: hydrogen storage system formed by a vessel or group of vessels, built over a unique structure (rack, container, skeleton trailer, etc.) and shipped individually that is storing and supplying hydrogen as a single unit

KP-1: Capital costs include all necessary components to operate the storage system, including compression (120 bar) and purification. The costs are referred to the mass of hydrogen recovered from the storage.

KPI-3: Based on the working mass of hydrogen stored, pure hydrogen considered.

KPI-4: Storage density of more than 40 kg-H₂ per m³ storage vessel. KPI applicable to compressed gas H₂, in spheres, tubes, pipes, per-stressed concrete containers, etc.

KP-5: Cost of the storage vessel including all necessary components to operate the storage system, including compression and purification, excluding pumping, liquefaction etc. The costs are reffered to the working mass of hydrogen

(KPI-4) and (KPI-5) should be reached together

Notes

Boundary Conditions: Assumed electricity price of 50€/MWh

KPI-1: Total quantity of energy required to convert normal hydrogen at 20 bar and 25 °C to liquid (para) hydrogen at 20 Kelvin and ambient pressure, expressed per kg of liquid hydrogen produced. This total quantity of energy includes electricity for compression drives, power requirements for (pre)cooling cycles and other pumping duties. Power recovery from expansion work from the LH₂ process may be subtracted from these power requirements.

KPI-2: Cost target for hydrogen liquefaction expressed as total cost attributable to the hydrogen liquefaction system as OPEX, as well as annualised CAPEX, per kg of hydrogen liquefied.

KPI-3:  Total cost attributable to a hydrogen carrier system to supply, on average, 1000 tpd of Hydrogen over a round trip distance of 3000 km, expressed on a Per KG hydrogen delivered basis.  Hydrogen supply conditions: 20 bar and ambient temperature, Hydrogen delivery pressure: 20 bar and ambient temperature, ISO14687 quality. Total cost includes Opex and Capex elements required, including cost for inventorising the supply chain, as well as operational make up cost due to carrier loss/degradation. The transportation cost includes the loading of the molecule, the cost of the transportation (including ship, fuel, personnel, maintenance...) and the unloading of the molecule to the on shore tank. To make it easy: "from on shore tank to on shore tank all inclusive.

KPI-4: Carrier energy consumption for 3000km distance. Boundaries: from hydrogen conversion into a dispatchable form to the hydrogen recovered, including carrier supply chain/degradation, except hydrogen production. Total quantity of energy required by the hydrogen carrier system (including shipping) to deliver hydrogen from supply point to delivery point under the boundary conditions as specified for KPI 3

Notes:

General for pipelines: KPIs for H₂ pipelines should be developed further based on expected H₂ transport in Europe by 2030 (e.g. pipeline capacity, pipeline diameter and cost of transport

KPI-1: For an 8-inch diameter pipeline, excluding right-of-way - 100% hydrogen new construction.

KPI-3: Percentage of hydrogen transported

KPI-4: Payload capacity = quantity of hydrogen contained in the trailer

KPI-5: CAPEX of the Lorry (excluding tractor), including cylinders’ racks, chassis and piping interconnexion

KPI-6: Operating cylinder Pressure.

KPI-7: LH₂ quantity in kg contained by the trailer. (This is practically equal to the LH₂ delivered)

KPI-8: Lorry CAPEX, including chassis and valving system but excluding the tractor cost, Estimate is cost is representing the case where with hundreds of units per year.

KPI-9: Quantity of liquid hydrogen boiled off after a day as a percentage of the total payload. Lorry fully load - trailer in standby, stop in a parking place 2hrs (no motion) - The % loss is based on the nominal capacity.

KPI-10: Quantity in T of Hydrogen stored in one single storage. Concerning the tank capacity, please consider: 125 t = 1,500 m³, 1,400 t = 20,000 m³

KPI-11: Full CAPEX incl. installation. Scope includes all equipment and tank installation without civil work (too dependent of the location), without any compression system (pumps or others) and without the pipe connexion from the LH2 unit or to the loading system. Costs assumed for production of a few units per year for 2024 and few tenths per year in 2030.

KPI-12: The boil-off is measured as a percentage of the nominal capacity

KPI-13: Quantity in T of Hydrogen stored in one single storage, real quantity in the tank including "un pumping" inventory

KPI-14: Full CAPEX incl. installation, the scope is the storage only with all equipments (valves, support...) but not the ship

KPI-15: Potential usage of the boil-off is not considered at this point. All data are without this optimisation. % of the total capacity

Notes:

KPI-1: Time that a maintained compressor system, with its minor components/parts (no core) being replaced, is able to operate until End-of-Life (EoL) criterium is met. For mature technology (TRL≥6), the main EoL criterium is the optimisation of total cost of system (evaluated as TCO, total cost of ownership as CAPEX + n∙OPEX(n), with OPEX dependent by time [year(n)] due to performance degradation). In mathematical terms, assuming a linear time degradation, lifetime is expressed in years as the square root of the ratio between CAPEX and yearly degradation (expressed as the yearly increment of maintenance and consumption cost due to the degradation of performance with respect to Beginning-Of-Life – BoL -, i.e., additional substitution spare parts). For emerging technology (TRL ≤5), EoL criterium assumes compression system (core parts) achieved the 90% of BoL performance (as compressed flow rate or pressure ratio).

KPI-2: Energy consumption to compress a kilogram of H2 from 5 bar(a) to 100 bar (without considering cooling power). Inlet pressure 5 bar(a), outlet pressure 100 bar(a) sufficient for most pipeline streams. This KPI is specifically for Pipeline application, and large-scale compression system (>1000 kg/d). Energy consumption needs only for the compression process, not include the cooling power. For mature tech (TRL≥6), KPI is focused on the system level, while for innovative tech (TRL ≤5), it regards the core part of technology.

KPI-3: Energy consumption to compress a kilogram of H₂ from 30 bar(a) to 900 bar(a). This KPI is specifically for HRS application, and mid-scale compression system (200-1000 kg/d). Energy consumption needs only for the compression process, does not include the cooling power. For mature tech (TRL≥6), KPI is focused on the system level, while for innovative tech (TRL ≤5), KPI regards the core part of technology.

KPI-4: Mean time between failure (or stoppage) of the system that render the system inoperable without maintenance. PI connected to the technology. Reliability should be estimated by sufficient failure events in proper long-term tests. For mature tech (TRL≥6), failure can be associated to rupture, wear, degradation of compressors parts which occurs without correct maintenance while for innovative tech (TRL ≤5), failure focus exclusively on the key element of technology (e.g., membrane, electrochemical cell, or active material)

KPI-5: Ratio of the maintenance costs, both fixed and variable (including overhaul cost, repair cost, replacement cost, maintenance cost) per unit of compressed hydrogen output. Energy cost is not considered.  Values is estimated as the ratio of total O&M cost (typical as annual percentage of CAPEX) and the yearly amount of compressed hydrogen, considering compressor availability/operating time about 100% (8760 hrs.). Same boundaries conditions as for KP-2 and KPI-3 for pipeline and HRS.

KPI-6: Capital cost of manufacturing of the compressor device (capital cost of system) normalised to the daily nominal capacity of the system. Fluid is pure hydrogen compliance with ISO 14687:2019. Same boundaries conditions as for KP-2 and KPI-3 for pipeline and HRS.

KPI-7: Concerning purification system.

KPI-8: Energy consumption to separate hydrogen from mixture. This KPI regards separation process, where it is necessary to extract hydrogen from a mixture with low hydrogen content. (e.g. H₂ from gas grid). Energy consumption must take in consideration pressure and temperature requirements of the process. Additional efforts (compression, thermoregulation) should be taken in account to normalise the energy cost with respect to reference case (feed stream pressure 30 bar, temperature 300K). For mature tech (TRL≥6), KPI is focused on the system level, while for innovative tech (TRL ≤5), it regards the core part of technology.  The feed/inlet H₂ molar fraction must be between 0.1 to 0.75. KPI should be evaluated with a minimum recovery rate of hydrogen about 80%. Output H₂ molar fraction must be > 99%

KPI-9: Energy consumption to purify hydrogen. This KPI regards purification process, where it is necessary to extract hydrogen from a mixture with high hydrogen content. (e.g. syngas). KPI for high TRL technology should be considered on the overall system, while it should be focused on the key components for low TRL technology. Energy consumption must take into consideration the technology's requirements for pressure or temperature. Additional efforts (compression, thermoregulation) should be taken in account to normalise the cost with respect to reference case (feed stream pressure 30 bar, temperature 300K).

KPI-10: Ratio between output purified hydrogen flow and hydrogen content into the input feed flow. For high technology TRL this regards overall purification/separation system. For low technology TRL, KPI focuses on the key elements of technology as membrane/electrochemical cell/active material. Output feed must be in compliance with ISO 14687:2019. Molar fraction in feed gas H₂ for separation application should be in range between 0.1-0.75 molar fraction in feed gas H₂ for purification application should be in range between 0.75-0.9995.

KPI-11: Levelised cost of separation or purification process, expressed as the cost for the processed mass of H₂ in kg. KPI focus exclusively for high TRL technology. Minimum hydrogen recovery factor is 80%. Output H₂ molar fraction must be > 99% or in compliance with ISO 14687:2019 for purification application, where it needs 

 Notes:

KPI-1: Station energy consumption per kg of hydrogen dispensed when the station is loaded at 80% of its daily capacity – For HRS which stores H₂ in gaseous form, at ambient temperature, and dispense H2 at 700bar in GH₂ from a source of >30 bar hydrogen.

KPI-2: Percent of hours that the hydrogen refuelling station is able to operation versus the total number of hours that it is intended to be able to operate (consider any amount of time for maintenance or upgrades as time at which the station should have been operational).

KPI-3: Mean time between failures (MTBF). How long the HRS will run before failing. A filling failure is stated when the fuelling cannot reach 80% of the reservoir capacity.

KPI-4: Parts and labour based on a 200 kg/day throughput of the HRS. Includes also local maintenance infrastructure. Does not include the costs of the remote and central operating and maintenance centre.

KPI-5: Person-hours of labour for the system maintenance per 1,000 h of operations over the station complete lifetime.

KPI-6: Total costs incurred for the construction or acquisition of the hydrogen refuelling station, including on-site storage. Exclude land cost & excluding the hydrogen production unit. Target ranges refer to stations’ capacity between 200-1,000 kg/d. CAPEX is dependent on the size of the station, the number of dispensers, the profile of consumption required, the need for buffers, the design.

KPI-7: Contribution of the HRS to the final cost of the hydrogen dispensed, amortisation and O&M costs included. Hydrogen production and transport is not considered. Public subsidies are excluded

Notes:

KPI-1: FC module is defined as FC stack plus air supply system, cooling system, internal ECU, media manifold and other BOP (recirculation, humidifier, sensors, DCDC, etc).  Based on an annual production rate of 2,500 units in 2024 and 25,000 units in 2030.

KPI-3: The durability target account for less than 10% performance loss at nominal voltage.

KPI-4: FC stack cost includes all the costs related to all components (materials, manufacturing, assembling) from electrodes to end-plates. Linked to FC stack durability, FC stack Power Density, PGM Loading.

KPI-5: Power density in W/cm² (referring to the active geometric area of the electrodes) at a defined cell voltage. Linked to FC stack efficiency, PGM Loading. Low TRL figures are also valid for all types of end-use applications, not only HDV vehicles (as per the Building Blocks, Section 3.4.1).

KPI-6: Ratio of the PGM loading (in mg/cm²) over the power density (in W/cm²) at a defined operating point in voltage. Linked to FC stack cost, FC stack Power density, FC stack efficiency. Low TRL figures are also valid for all types of end-use applications, not only HDV vehicles (as per the Building Blocks, Section 3.4.1).

KPI-7: Total cost of the CGH₂ storage tank, including one end-plug, the in-tank valve injector assembly assuming 200,000 units/year in 2030.

KPI-8: Total cost of the LH₂ storage tank, including one end-plug, the in-tank valve injector assembly assuming 200,000 units/year in 2030.

KPI-9: Mass of stored compressed gaseous hydrogen divided by the mass of the system (included mass of hydrogen), at tank system level. KPI-9: % of the available design space. In a given, cuboid space, the internal capacity of the tank uses only around 25% of the available design space. Idea of conformable tanks are being promoted, seeking to use up to 55% of the design space in 2030.

KPI-10: Ratio between the volume where the H2 fluid is stored and the corresponding parallelipedic volume in which the system has to be installed

KPI-11 Mass of stored liquid hydrogen divided by the mass of the system (included mass of hydrogen), at tank system level.

KPI-12: Mass of stored hydrogen (in grams) divided by the outer volume of the system (in litres)

Notes:

KPI-1: Power output of fuel cell based power generation (FC system output power)

KPI-2: Bunkering capacity of hydrogen in compressed, liquid form or as part of another hydrogen carrier (shore to ship infrastructure).

KPI-3: Lifetime of integrated fuel cell systems in maritime conditions and associated operation profile, not excluding the replacement of fuel cell stacks and system components at SoA intervals.KPI-4: Type approval on FC and H₂ storage solutions. To allow products to be used for maritime propulsion beyond prototype phase, products need to be type approved.

KPI-4: Type approval is a procedure for the approval of the product design for compliance with classification or flag administration requirements. The type approval is a mandatory requirement for critical apparatus installed on any classified vessel.

KPI-5: CAPEX of PEMFC for shipping per kW of power at certain (low) production volume. FC module is defined as FC stack plus air supply system, cooling system, internal engine control unit, media manifold and other BoP (recirculation, humidifier, sensors, DC-DC converter, etc)

 Notes:

KPI-1: The durability target account for less than 10% performance loss at nominal voltage.

KPI-5: If we consider 16 h/day of operating hours at FC level and 5 start/stops during the day => 4,687 for 15,000 h.

KPI-6: Percent of time vehicle is in operation against planned operation and related to FC system

KPI-7: Hydrogen consumption for 100 km driven under operations using exclusively hydrogen feed. Based on standard cycle EN50591, unit => [kg/100km/ton]. Standard cycle is a flat profile (low demanding power, no heating, ventilation, and air conditioning)

KPI-8 and KPI- 9: FC system is defined as FC plus BoP (including cooling system). It excludes tanks and DC-DC converter

 Notes:

KPI-1: Durability target account for less than 10% performance loss at nominal voltage between beginning of life  and end of life

KPI-2: Fuel cell efficiency at system level shall include stack and balance of plant (cathodic ancillaries incl. compressor, anodic ancillaries excl. H₂ storage, thermal management incl. heat exchanger, controls, excl. power converters). KPI target depend on application and will vary between a propulsive FC system for light aviation and SMR APU or hybridised power unit.

KPI-3: FC system availability is defined, in the case of aviation, by the ratio of successful system start.  Global reliability of the system (i.e. in service failure rate/hour) will have to comply with conventional aviation certification KPI (10^-9 failure/hour). Nevertheless, the efficiency as defined above (ratio of successful system start) is key for economic viabilityKPI-4: gravimetric density at system level shall include stack and balance of plant (cathodic ancillaries incl. compressor, anodic ancillaries excl. H₂ storage, thermal management incl. heat exchanger, controls, excl. power converters).

KPI-5: Gravimetric efficiency of storage tank, mass of stored hydrogen divided by the mass of the system (included mass of hydrogen). The system is based on a vacuum double layers tank technology. The tank volume target is more than 1 ton of LH₂, with minor boil-off after 2 days.

KPI-6: Continuous fuel flow supplied to the system during peak power / climb (15 minutes) and conventional operation of the aircraft (cruise- few hours), defined in kg/hr. A similar KPI may be set for turbine aircraft, as soon as the exact configuration is defined within Clean Aviation

 Notes:

Standard boundary conditions that apply to all SOFC system KPIs: Input of bio-methane, tap water (if necessary) and ambient air; output of electrical power and heat. Correction factors may be applied if different fuel is used. For KPI – 3.2 Input of hydrogen from pipeline (above 99%), tap water (if necessary) and ambient air; output of electrical power and heat. The selected power range exclude larger fuel cells at MW scale. Multi-MW scale fuels cells will consist of FC system modules of max 500 kWe. For reversible fuel cells running in electrolyser mode the KPIs defined under the hydrogen pillar for high temperature electrolysers can be used.

KPI-1: Capital cost are based on 100 MW/annum production volume for a single company and on a 10-year system lifetime running in steady state operation, whereby end of life is defined as 20% loss in nominal rated power. Stack replacements are not included in capital cost. Cost are for installation on a prepared site (fundament/building and necessary connections are available). Balance of plant components are to be included in the capital cost. Capital costs doesn’t include margins, distribution and marketing costs.

KPI-2: Operation and maintenance cost averaged over the first 10 years of the system. Potential stack replacements are included in O&M cost. Fuel costs are not included in O&M cost.

KPI-3: Electrical efficiency is ratio of the net electric AC power (IEV 485-14-03) produced by a fuel cell power system (IEV 485-1818 09-01) to the total enthalpy flow (fuel LHV) supplied to the fuel cell power system. Heat recovery efficiency is ratio of recovered heat flow of a fuel cell power system (IEV 485-09-01) to the total enthalpy flow (fuel LHV) supplied to the fuel cell power system. Total efficiency of fuel cell power system (ηtot) is a sum of electrical efficiency and heat efficiency.

KPI-4: The time a system was expected to operate minus the downtime, divided by the time a unit was expected to operate, expressed as a percentage. For micro-CHP demonstration, a minimum of ten units should be considered. For mid-scale or large-scale single units should be reported. Linked to O&M Cost (KPI-2): if maintenance interval is increased, then the availability of in base load running units will be also increased (i.e. 1 week in two years for maintenance).

KPI-5: Warm Start Time is equal to hot idling condition, when system is electrically disconnected and the connection will be restored again. This condition should cover grid disconnection events.

KPI-6: Stack degradation defined as percentage power loss when run starting at nominal rated power at BoL for fuel composition specified by stack manufacturer at constant current intensity (CI) and fuel utilisation (FU) of 75%. For example, 0.125%/1,000h results in 10% power loss over a 10-year lifespan with 8,000 operating hours per annum. Values are for steady state operation. Minimum test time = 3,000 hours.

KPI-7: Stack production cost are based on 100 MW/annum production volume for a single company. Stack production costs doesn’t include margins, distribution and marketing costs.

KPI-8: Roundtrip electrical efficiency is energy discharged measured on the primary point of connection (POC) divided by the electric energy absorbed, measured on all the POC (primary and auxiliary), over one electrical energy storage system standard charging/discharging cycle in specified operating conditions. Only valid for rSOC systems

 Notes:

Standard boundary conditions that apply to all PEMFC system KPIs: input of hydrogen, tap water (if necessary) and ambient air; output of electrical power and heat. Correction factors may be applied if different fuel is used.

KPI-1: Capital cost are based on 100 MW/annum production volume for a single company and on a 10-year system lifetime running in steady state operation, whereby EoL is defined as 20% loss in nominal rated power. Stack replacements are not included in capital cost. Cost are for installation on a prepared site (fundament/building and necessary connections are available). For PEMFC the EBOP (Power Conversion System or electrical balance of plant components) have not been included in capital costs. Capital costs doesn’t include margins, distribution and marketing costs.

KPI-2: Operation and maintenance cost averaged over the first 10 years of the system. Potential stack replacements are included in O&M cost. Fuel costs are not included in O&M cost.

KPI-3: Electrical efficiency at beginning of life (η_el) is ratio of the net electric DC power (IEV 485-14-03) produced by a fuel cell power system (IEV 485-1818 09-01) to the total enthalpy flow (fuel LHV) supplied to the fuel cell power system.

KPI-4: (The time a system was expected to operate minus the downtime) divided by (the time a unit was expected to operate) expressed as a percentage.

KPI-5: Time required to reach the nominal rated power output when starting the device from warm standby mode (system already at operating temperature).

KPI-6: Stack degradation defined as percentage power loss compared to nominal rated power at BoL for fuel composition and utilisation specified by stack manufacturer at constant current (density). Minimum testing time of 3,000 hrs (4 months)

KPI-7: Stack production cost are based on 100 MW/annum production volume for a single company. Stack production costs doesn’t include margins, distribution and marketing costs.

KPI-8: The critical raw material considered here is Platinum

Notes:

KPI-1: Hydrogen percentage content in gas turbine fuel, by mass (volume).

Boundary Conditions: applicable only to DLE technology. WLE technologies are not in scope. While state-of-the-art gas turbines can already handle 20% hydrogen by vol (blended in natural gas), development of gas turbines (and more specifically combustors) able to handle 0-100% H₂ is a challenging and necessary task. Gas turbines operating in the range 0-100% H₂ are required by users in the power generation market to ensure security of power supply in case of H₂ shortages or lack of availability. Development of such combustors can be reached by gradually increasing the amount of H₂ in gas turbines in the years to come to reduce technical risks.

KPI-2: NO_x (NO + NO2) content in exhausts.

Boundary conditions: A fuel switch to hydrogen aims to retain all present strengths and ensure carbon-free energy conversion. Although the technological development of GT combustors aims to minimise NO_x emissions, an increase in NO_x formation is expected as the hydrogen content in the fuel is increased. This is a consequence of the higher reactivity of hydrogen and the related impact on flame stability, flame temperature etc. Conserving the same low-NO_x emissions level of 25 ppmv@15%O₂/dry when advancing from 30% (by volume) to 100% H₂ remains a challenge. The conventional NO_x normalisation method (15%O2/dry) is not designed to be translated across different fuels with different reactivity and exhaust gases. A more appropriate normalisation for NO_x emissions is expressed in mg/MJ of fired-power, and therefore the KPI table also provides this alternative normalisation.

KPI-3: Hydrogen content during gas turbine start-up.

Boundary conditions: during start-up gas turbines are commonly fuelled with natural gas or liquid oil.

KPI-4: Reduction in electric efficiency of power plant when hydrogen-firing of the gas turbine is introduced (overall efficiency of power plant may be unaffected or increased through CHP schemes)

Boundary conditions: Evaluated at Full Speed Full Load condition. It refers to combined cycle gas turbines with bottoming steam cycle (CCGT). For the SoA, the actual maximum efficiency reduction is class-specific and largely depends on the class of the gas turbine.KPI-3: H₂ content during gas turbine start up (during start up gas turbines are commonly fuelled with natural gas or liquid oil)

(KPI-4) and (KPI-2) are interdependent, increasing efficiency may increase NO_x emissions, thus these two parameters require optimisation.

KPI-5:  Percentage variation per minute of the gas turbine load with respect to the full load

KPI-6: Gas turbine ability to operate stably when facing unexpected H₂ content in fuel. Evaluated with respect to nominal H₂ content in fuel composition (blend of natural gas and H₂)

Notes:

KPI-1: [amount recycled]/[amount present in the whole system (including main equipment and BoP)] in %

KPI-2: amount of Pt recycled from FC/ electrolysers at end-of-life

KPI-3: amount of ionomer recycled from FC/electrolysers at end-of-life

These recycled rate values refer to a TRL 7 (system prototype demonstration in operational environment)

 Notes:

(General) These KPI's consider different awareness levels in the EU based on the HyLaw analysis, target are set for each of the 3 tiers:

• Tier 1 countries: Germany, Denmark, United Kingdom and France;
• Tier 2 countries: Belgium, Netherlands, Austria, Sweden, Norway, Finland, Latvia, Spain and Italy;
• Tier 3 countries: rest of EU countries and associated countries

KPI-1: Number of trained pupils (primary and secondary education).

KPI-2: Number of trained professionals (qualified workers, technicians and engineers).

KPI-3: Number of educative centres and/or universities offering higher education course modules and/or fully dedicated educational programmes on hydrogen and/or fuel cells (included in existing curricula and not full academic diploma on hydrogen exclusively)

 Notes:

KPI-1: Critical projects with pro-active safety management, including a periodically reviewed safety plan, educational measures, monitoring, etc. in percentage. Critical projects will be identified by the European Hydrogen Safety Panel, which will also assess the project safety management.

KPI-2: Projects reporting on safety (no events, near misses, incidents, accidents). Definitions of near-miss, incident, and accident according to EIGA document (INCIDENT/ACCIDENT INVESTIGATION AND ANALYSIS SAC Doc 90/13/E). Off-normal conditions to be reported in HIAD2.0 and/or HELLEN databases.

KPI-3: Number of safety workshops (e.g. on research priorities, risk assessment, end-use safety, etc.) and/or PNR/RCS workshops (e.g. permitting procedures for end-use installations, gaps analyses in specific aspects of the supply chain, etc.) at the programme level.

KPI-4: Number of Standards, Technical Specifications or Technical Reports at the scope of a PNR project. The impact will be measured after the end of the project, because of the different timelines of a PNR project and the SDO activities