Green Hydrogen Production Viability in Northern Ireland

Illustration of Northern Ireland highlighting hydrogen infrastructure

This tool explores the feasibility and economic viability of green hydrogen production in Northern Ireland, incorporating:

Renewable electricity availability (e.g. wind and solar)
Hydrogen production technologies and pathways
Infrastructure and deployment constraints
Techno-economic cost modelling to support decision-making

Created by Hollie Picking

Under the supervision of Dr Paul Kavanagh and Dr Nathan Skillen

Analysis and data compiled in 2025

Project Parameters

Electrolyser Type:

PEM
£829,500/MW

Alkaline
£592,500/MW

Electrolyser Capacity (MW):

Electrolyser Efficiency (kWh/kg H₂):

Electrolyser Up-time (%):

Note: Electrolyser uptime is directly linked to site specific renewable energy data. Adjust this value accordingly.

Project Life (years):

System Flow Diagram:

Cost Parameters

Electricity Supply Type:

Grid Connected

Hybrid Renewable Installation

Wind Capacity Factor (%):

Typical range: 20-45% (Northern Ireland average: 26.8%). Set to 0 for solar-only.

High Wind Site: A capacity factor above 40% represents an exceptional wind resource for Northern Ireland. Most sites will not achieve such high outputs. Please verify this matches your specific site wind data and local conditions.

Wind Installed Capacity (MW):

Total wind farm capacity to be installed. Set to 0 for solar-only.

Solar Capacity Factor (%):

Typical range: 10-15% (Northern Ireland average: 12%). Set to 0 for wind-only.

Solar Installed Capacity (MW):

Total solar farm capacity to be installed. Set to 0 for wind-only.

Hydrogen Storage Type:

High Pressure Storage Tanks

Liquid Organic Hydrogen Carrier

Methanol Conversion

Ammonia Conversion

Hydrogen Transport Type:

Road Delivery via Tube Trailer

Existing Pipeline

On-Site Refueller

Water Standing Charge (£/year):

Water Variable Cost (£/m³):

Maintenance Rate (% of CAPEX/year):

System Interconnection (% of project CAPEX):

Annual Insurance Estimate (% of project CAPEX/year):

Land Cost (£/acre):

Backup Power:

No Backup Power

Battery Backup

Fuel Cell Backup

Note: Backup power is only for cases of no renewable input, to ensure safety systems, welfare facilities and controls can stay operational. This is unlikely to be used to run the electrolyser system.

Backup Power Capacity (MW):

Recommended: Match or exceed electrolyser capacity for full backup

Hydrogen Sales Price (£/kg):

📊 Project Economics

£0

Total CAPEX

£0

Annual OPEX

H₂ Production (kg/year)

£0

LCOH (£/kg H₂)

£0

Expected Annual Revenue

(Hydrogen sales only - potential for additional oxygen revenue)

Payback Period (years)

💰 CAPEX Breakdown

Renewable Installation: £0

Electrolyser Equipment: £0

Compression Equipment: £0

Storage Equipment: £0

Transport Equipment: £0

Battery Backup System: £0

System Interconnection (15% of total project): £0

Land Acquisition: £0

Planning Permissions: £0

Environmental Impact Assessment: £0

Welfare Facilities: £0

Total CAPEX: £0

🔄 Annual OPEX Breakdown

Electricity Cost: £0

Water Cost (Standing + Variable): £0

Renewable O&M: £0

Electrolyser Maintenance (3% electrolyser CAPEX): £0

Stack Replacement (Annualized): £0

Compression O&M (2% Compressor CAPEX): £0

Storage O&M (2% Storage CAPEX): £0

Transport Cost: £0

Annual Backup Power O&M (2% of System CAPEX): £0

System Replacement (Annual reserve over 5 years): £0

Staff Cost: £0

Annual Insurance Estimate (2% of project CAPEX/year): £0

Total Annual OPEX: £0

🔬 Electrolyser System Analysis

Electrolyser Type: PEM Electrolyser

Electrolyser Capacity: 0 MW

Efficiency Rating: 0 kWh/kg H₂

Annual Operating Hours: 0 hours

Total Electrolyser CAPEX: £0

• Stack Assembly (60%): £0

• Power Electronics (20%): £0

• Balance of Plant (15%) (including water purification, hydrogen safety equipment, etc.): £0

• Installation & Commissioning (5%): £0

Stack Replacement Interval: 0 years

Stack Replacement Cost (per occurrence): £0

Total Stack Replacements (25 years): 0

Stack Replacement Schedule: Years: 0

Annual Maintenance Rate: 3% of electrolyser CAPEX

Annual Maintenance Cost: £0

PEM Advantages: Higher efficiency, faster response times, better suited for variable renewable input, produces higher purity hydrogen, but higher initial cost and more frequent stack replacement.

💨 Hydrogen Compression Analysis

Annual H₂ Production Capacity: 0 kg/year

Compression Equipment CAPEX: £0

Annual Compression OPEX: £0

Note: Specific compressor data is unavailable for the exact inlet and outlet pressures, so the model uses the higher end of the cost range to account for unknowns.

🗃️ High Pressure Storage Analysis

Storage Type: High Pressure Tanks

Annual H₂ Production: 0 kg/year

Storage Cost Rate: £0.26/kg H₂

Storage Equipment CAPEX: £0

Annual Storage OPEX: £0

🚛 Road Transport Analysis

Transport Type: Road Delivery via Tube Trailer

Annual H₂ Production: 0 kg/year

Transport Cost Rate: £1.23/kg H₂

Transport OPEX Rate: 2% of Transport CAPEX

Transport Equipment CAPEX: £0

Transport OPEX: £0

🔋 Backup Power System Analysis

Backup Power Status: Included

Backup Power Capacity: 0 MW

System Cost Rate: £158,000/MW

Backup Power System CAPEX: £0

System Lifetime: 12 years

Replacements Over 25 Years: 1 replacement

Total Replacement Cost: £0

Annual Replacement Cost (Annualised): £0

Note: Annual replacement costs are factored in for years 1–12, covering the savings for a battery replacement after year 12. This operating expense will be discontinued after the replacement, as a second replacement at year 24 of a 25-year project is not considered economically viable.

Annual Backup Power O&M (2% of System CAPEX): £0

💨 Oxygen Production Analysis

Annual H₂ Production: 0 kg/year

H₂ to O₂ Mass Ratio: 1:8 (stoichiometric)

Annual O₂ Production: 0 kg/year

Estimated O₂ Market Value (£180.96/tonne): £0/year

Note: Oxygen sales could provide additional revenue depending on local market conditions, purity requirements, and proximity to industrial customers. Common applications include steel production, chemical processes, and wastewater treatment.

🏞️ Land Requirements Analysis

Electrolyser Capacity: 0 MW

Electrolyser Land Requirement: 0 acres

Renewable Capacity: 0 MW

Renewable Land Requirement: 0 acres

Total Land Required: 0 acres

Total Land Cost: £0

Note: Electrolyser and solar land requirements would fit within wind farm spacing

💰 25-Year Cash Flow Analysis

Initial CAPEX Investment: £0

Annual Revenue: £0

Annual OPEX: £0

Annual Net Cash Flow: £0

Total 25-Year Revenue: £0

Total 25-Year OPEX: £0

Total 25-Year Net Cash Flow: £0

Project NPV (8% discount rate): £0

Internal Rate of Return (IRR): 0%

Project Viability: Analyzing...

📊 Year-by-Year Cash Flow Table

Year	Revenue	OPEX	Net Cash Flow	Cumulative Cash Flow	NPV Factor	Discounted Cash Flow

📈 Cumulative Cash Flow Chart

■ Negative Cash Flow ■ Positive Cash Flow ● Breakeven Point

📚 Model References & Assumptions

📚 References & Assumptions

🔍 Model Assumptions

[A1] Equipment Maintenance Downtime: Max 95% Availability

The equipment maintenance is approximately 5% of the year (2.5 weeks), therefore the economic model cannot exceed 95% availability. The availability will be related to the hourly wind data of a selected site.

[A2] Water Purification System Standards: Industry Standard

The assumption is made that Nel's water purification system is in line with industry norms, resulting in potable water inlet requirements in line with expected parameters.

[A3] Alkaline Water Consumption Equivalence: 15.9L/kg H₂

Nel does not provide a value for potable water consumption for alkaline electrolysers. Considering both PEM and Alkaline electrolysers require a feed water consumption of 10L/kg H₂, which equates to 15.9L/kg H₂ potable water consumption for PEM electrolysers, the assumption is used that alkaline units use the same water purification units and would therefore also require 15.9L/kg H₂ as potable water consumption.

[A4] Electrolyser OPEX Rate: 3% of CAPEX

Assumption that electrolyser OPEX costs are 3% CAPEX according to KPMG as referenced in Reference R17.

[A5] Stack Replacement Cost Projections: 2030 Targets

Assumption is made that the Krishnan et al cost predictions for PEM and Alkaline stack replacements in 2030 are achieved.

[A6] Equipment Lifetime: 25 Years

Assumption that with proper maintenance, the electrolysers, solar installations, wind turbines, refuellers etc will have an average lifetime of 25 years.

[A7] Annual Insurance Rate: 2% of CAPEX

Assumption that annual insurance is 2% of capital cost of project.

[A8] Water Standing Charge: £2,292

The NI Water standing charge is based on supply pipe size. The assumption is made that due to the volume of water used in green hydrogen production, that the maximum pipe size of 200mm would be used, resulting in a standing charge of £2,292 for the 2025/2026 period. Linked to Reference R22.

[A9] Staffing Requirements: 5 Engineers/10MW

Estimation of 5 engineers per 10MW each with gross cost of employment to be £50,000 to run the electrolyser plant. Minimum of 2 engineers on any site.

[A10] Welfare Facilities Cost: £100,000

An estimate of £100,000 has been included to build adequate welfare facilities, including toilets, meeting areas and canteen facilities.

[A11] Solar OPEX Rate: 1% of CAPEX

Determining a precise OPEX cost for solar panels has been challenging, therefore an assumption of 1% has been used based on data provided by solar PV supplier Lumify Energy.

[A12] Storage Infrastructure Inclusion: All-Inclusive LCHS

The LCHS is assumed to include the cost of all required infrastructure to facilitate the storage (storage tanks, methanol conversion equipment etc).

[A13] Storage OPEX Rate: 2% of CAPEX

The OPEX of numerous storage solutions is unknown and estimated at 2% CAPEX of the equipment.

[A14] Road Transport Equipment Inclusion: Equipment Inclusive

Road transport costs are assumed to be inclusive of the necessary transport equipment such as hydrogen tube trailers.

[A15] Road Transport OPEX: 5% of CAPEX

Road transport does not consider fuel cost as this is dependant on distance to offtaker therefore an OPEX of 5% CAPEX has been included to account for drivers, insurance and fuel.

[A16] Pipeline Repurposing: Existing Infrastructure

The pipeline costs are relative to repurposing existing pipelines, avoiding the expense of new network construction.

[A17] Transport OPEX Rates: 5% / 1% / 2%

The OPEX of transport solutions is unknown and dependant on distance between producer and offtaker, therefore an estimation at 5% CAPEX is used for road transport. An OPEX estimation of 1% CAPEX is used for pipeline transport and 2% CAPEX for on-site refueller.

[A18] Land Type Selection: Agricultural Land

Assumption that purchasing a large site in Northern Ireland would have to be agricultural land to fit a large plant. Agricultural land is recorded to be priced on average at £14,736 per acre [R37].

[A19] Land Overlap Optimization: Wind Site Integration

If wind is the renewable electricity source, additional acreage is not required for the electrolyser or solar installations on top of the required for wind as the hydrogen production equipment is assumed to fit within the free areas on the wind site. If solar alone is the renewable electricity source, then additional land will be required as solar will require all physical ground space.

[A20] Compressor OPEX Addition: 2% Additional OPEX

The assumption that the €1.75/kg H₂ price used for Compressor CAPEX includes electricity consumption, its full inclusion of OPEX isn't explicitly confirmed. Therefore, to ensure our pricing remains robust and conservative, an additional 2% for operational expenditure will be included.

[A21] Grid Connection Land Requirement: 5 Acres

Assumption that if a grid connection is chosen, an additional 5 acres of space will be suitable to fit all ancillary equipment and give enough space for maintenance etc.

[A22] BoP Electricity Requirement: 5% of Electrolyser

Assumption that the BoP and welfare facilities electricity requirement would be 5% of the electrolyser electricity requirements.

[A23] Battery System OPEX: 2% of CAPEX

The OPEX of battery systems is unknown, therefore an estimation at 2% battery CAPEX is assumed.

[A24] Fuel Cell System OPEX: 2% of CAPEX

The OPEX of hydrogen fuel cell system is unknown, therefore an estimation at 2% fuel cell CAPEX is assumed.

📖 Source References

[R1] USD to GBP Cost: 1 USD = 0.79 GBP

Based on the currency exchange rate on 15th Feb 2025.

[R2] EUR to GBP Cost: 1 EUR = 0.85 GBP

Based on the currency exchange rate on 6th April 2025.

[R3] Price per MW PEM Electrolyser: £829,500.00

As stated in Table 6 in IRENA's Green Hydrogen Cost Reduction Paper, the price for PEM electrolysers is in the range of 700-1400 USD/kW. Price used in model will be the midpoint (1050USD/kW). Based on the current exchange rate of 1USD to 0.79GBP, the value in the model will be £829,500 per MW.

Source: International Renewable Energy Agency. (2020). Green Hydrogen Cost Reduction: Scaling up Electrolysers to Meet the 1.5⁰C Climate Goal. Abu Dhabi: International Renewable Energy Agency. Page 65.

[R4] Price per MW Alkaline Electrolyser: £592,500.00

As stated in Table 6 in IRENA's Green Hydrogen Cost Reduction Paper, the price for alkaline electrolysers is in the range of 500-1000 USD/kW. Price used in model will be the midpoint (750USD/kW). Based on the current exchange rate of 1USD to 0.79GBP, the value in the model will be £592,500 per MW.

[R5] Average H₂ Production per MW for PEM Electrolyser: 17.7kg/hr
196.8Nm³/hr

As stated in Nel's Alkaline and PEM Electrolyser comparison document, an MC500 PEM electrolyser equivalent to an approx. 2.5MW system operating at full capacity produced 492Nm³/hr or 1,061kg/day. Based per MW for the model, this equates to 196.8Nm³/hr per MW using a PEM electrolyser. The same approach for the net production rate in kg/day based on 24hr operation produces a value of 17.7kg/hr hydrogen production per MW.

Source: Nel. (2025, April 06). Alkaline and PEM Electrolysers. Retrieved from Nel: https://nelhydrogen.com/resources/electrolysers-brochure/

[R6] Average H₂ Production per MW for Alkaline Electrolyser: 17.4kg/hr
194Nm³/hr

As stated in Nel's Alkaline and PEM Electrolyser comparison document, an A485 alkaline electrolyser equivalent to an approx. 2.5MW system operating at full capacity produced 485Nm³/hr or 1,046kg/day. Based per MW for the model, this equates to 194Nm³/hr per MW using an alkaline electrolyser. The same approach for the net production rate in kg/day based on 24hr operation produces a value of 17.4kg/hr hydrogen production per MW.

Source: Nel. (2025, April 06). Alkaline and PEM Electrolysers. Retrieved from Nel: https://nelhydrogen.com/resources/electrolysers-brochure/

[R7] Potable Water Consumption for PEM Electrolysers: 15.9L/kg H₂

As stated in Nel's Alkaline and PEM Electrolyser comparison document, an MC500 PEM electrolyser required 10L/kg H₂ of feed water or 15.9L/kg H₂ of potable water to be consumed in the PEM electrolyser. The assumption is made that Nel's water purification system is in line with industry norms, resulting in potable water inlet requirements in line with expected parameters. [Link to Assumption A2]

Source: Nel. (2025, April 06). Alkaline and PEM Electrolysers. Retrieved from Nel: https://nelhydrogen.com/resources/electrolysers-brochure/

[R8] Potable Water Consumption for Alkaline Electrolysers: 15.9L/kg H₂

Nel's Alkaline and PEM Electrolyser comparison document shows that the value of potable water required for alkaline electrolysers is not provided by Nel, however, the feed water to electrolysis is stated as 10L/kg H₂. The PEM unit also consumes 10L/kg H₂ as feed water, therefore it is assumed that using the same water purification system, that 15.9L/kg H₂ of potable water is also required by the alkaline unit. [Link to Assumption A3]

Source: Nel. (2025, April 06). Alkaline and PEM Electrolysers. Retrieved from Nel: https://nelhydrogen.com/resources/electrolysers-brochure/

[R9] Electrical Efficiency of System for PEM Electrolyser: 66.5kWh/kg H₂

As stated in Table 6 in IRENA's Green Hydrogen Cost Reduction Paper, the electrical efficiency of the system is stated as 50-83kWh/kg H₂. This range reflects an approximate energy consumption value of 50kWh/kg H₂ at the Beginning of life (BOL), which increases to 83kWh/kg H₂ towards the End of Life (EOL) as stack performance degrades and the stack replacement is required. As above, the midpoint of 66.5kWh/kg H₂ will be used to provide a consistent representative value throughout.

[R10] Electrical Efficiency of System for Alkaline Electrolyser: 64kWh/kg H₂

As stated in Table 6 in IRENA's Green Hydrogen Cost Reduction Paper, the electrical efficiency of the system is stated as 50-78kWh/kg H₂. This range reflects an approximate energy consumption value of 50kWh/kg H₂ at the Beginning of life (BOL), which increases to 78kWh/kg H₂ towards the End of Life (EOL) as stack performance degrades and the stack replacement is required. As above, the midpoint of 64kWh/kg H₂ will be used to provide a consistent representative value throughout.

[R11] Delivery Pressure for PEM Electrolyser: 30bar

Delivery pressure for Nel matches typical PEM pressure output.

Source: Nel. (2025, April 06). Alkaline and PEM Electrolysers. Retrieved from Nel: https://nelhydrogen.com/resources/electrolysers-brochure/

[R12] Delivery Pressure for Alkaline Electrolyser: 0.03bar

Delivery pressure for Nel matches typical alkaline pressure output.

Source: Nel. (2025, April 06). Alkaline and PEM Electrolysers. Retrieved from Nel: https://nelhydrogen.com/resources/electrolysers-brochure/

[R13] Average Oxygen Production based on kg/hr: H₂ value × 8

Hydrogen value multiplied by 8.

Source: Maggio, G., Squadrito, G., & Nicita, A. (2022). Hydrogen and medical oxygen by renewable energy based electrolysis: A green and economically viable route. Applied Energy.

[R14] Average Oxygen Production based on Nm³/hr: H₂ value ÷ 2

Hydrogen value divided by 2.

Source: Stoichiometric calculation based on water electrolysis reaction.

[R15] PEM Stack Lifetime: 65,000 hours

The stack lifetime for PEM electrolysers is within the range of 50,000-80,000 hours. For consistency, the operating hours' midpoint of 65,000 will be used, which equates to approximately 7.4 years. The potential need for a third stack replacement at the 22.2 may be unnecessary, given that the remaining equipment has a shorter remaining lifespan, but has been accounted for to be conservative.

Source: International Renewable Energy Agency. (2020). Green Hydrogen Cost Reduction: Scaling up Electrolysers to Meet the 1.5⁰C Climate Goal. Abu Dhabi: International Renewable Energy Agency.

[R16] Alkaline Stack Lifetime: 60,000 hours

The stack lifetime for alkaline electrolysers is within the range of 60,000 hours, which equates to approximately 6.9 years. The potential need for a third stack replacement at the 20.7-year mark may be unnecessary, given that the remaining equipment has a shorter remaining lifespan, but has been accounted for to be conservative.

Source: International Renewable Energy Agency. (2020). Green Hydrogen Cost Reduction: Scaling up Electrolysers to Meet the 1.5⁰C Climate Goal. Abu Dhabi: International Renewable Energy Agency.

[R17] PEM/Alkaline Maintenance (OPEX Cost): 3% CAPEX

Maintenance OPEX costs for electrolysers is estimated at 3% of capital costs. Linked to Assumption A4.

Source: KPMG. (2022). How to evaluate the cost of the green hydrogen business case? London: KPMG.

[R18] PEM Stack Replacement Costs: £126.28/kW

The present and future costs of PEM electrolyser stacks are outlined in the Krishan, et al. 2023 paper, stating the 2020 cost for stack replacement for PEM electrolysers is €384-€1,071/kW, set to reduce significantly to €63-€234/kW by 2030. While the model's calculations are based on present day costs, the projected 2030 costs will be applied specifically for stack replacement, as this cost will occur 7.4 years after operation commences, which will fall beyond the year 2030. Remaining consistent with the use of the midpoint, an OPEX value of €148.50/kW or £126.28/kW will be added to the PEM electrolyser OPEX every 7.4 years based on April 6th exchange rate. This reference is linked to the assumption that the projected 2030 costs are achieved.

Source: Krishnan, S., Koning, V., de Groot, M. T., de Groot, A., Mendoza, P. G., Junginger, M., & Kramer, G. J. (2023). Present and future cost of alkaline and PEM. International Journal of Hydrogen Energy, 32313-32330.

[R19] Alkaline Stack Replacement Costs: £55.70/kW

The present and future costs of Alkaline electrolyser stacks are outlined in the Krishan, et al. 2023 paper, stating the 2020 cost for stack replacement for Alkaline electrolysers is €242-€388/kW, set to reduce significantly to €52-€79/kW by 2030. While the model's calculations are based on present day costs, the projected 2030 costs will be applied specifically for stack replacement, as this cost will occur 6.9 years after operation commences, which will fall beyond the year 2030. Remaining consistent with the use of the midpoint, an OPEX value of €65.5/kW or £55.70/kW will be added to the PEM electrolyser OPEX every 6.9 years based on April 6th exchange rate. This reference is linked to the assumption that the projected 2030 costs are achieved.

[R20] Annual PEM Stack Replacement Costs: Varying

Annual costs calculated based on £126,225 per MW replacement cost, multiplied by varying size of electrolyser, multiplied by 3 stack replacements over a 25 year lifetime of the electrolyser, divided by 25 year lifetime of electrolyser [Assumption A6]. Linked to prices in R18.

Source: Calculated value based on reference R18.

[R21] Annual Alkaline Stack Replacement Costs: Varying

Annual costs calculated based on £55,675 per MW replacement cost, multiplied by varying size of electrolyser, multiplied by 3 stack replacements over a 25 year lifetime of the electrolyser, divided by 25 year lifetime of electrolyser [Assumption A6]. Linked to prices in R19.

Source: Calculated value based on reference R19.

[R22] Price of Water: £1.45 per m³
Standing Charge of £2,292

The pricing for water is based on the NI Water variable charge at the time of the assessment, as of 6th April 2025 is £1.45 per m³. There is also an additional standing charge based on supply pipe size. Assuming the largest pipe size due to the volume of water required, the current standing charge is £2,292 for the 2025/2026 period. [Linked to Assumption A8]

Source: NI Water. (2025, April 06). Water, sewerage and trade effluent charges. Retrieved from NI Water: https://www.niwater.com/measured-charges/

[R23] Power NI Green PPA Price: £277.40 per MWh

As of 6th April, the standard household rate for Power NI's 100% green 'Eco Energy Standard Bill' is 27.74p per kWh, however it is likely this would be reduced for a high-volume business consumer.

Source: Power NI. (2025, April 6th). Eco energy tariff. Retrieved from Power NI: https://powerni.co.uk/compare-electricity-ni/green-electricity/eco-energy-tariff/

[R24] New Wind Installation Prices: £1,250,570/MW

1,583USD/kW converted to GBP based on exchange rate in model from IRENA average for onshore wind projects in Europe.

Source: IRENA. (2024). Renewable Power Generation Costs in 2023. Abu Dhabi: IRENA.

[R25] Wind OPEX Cost: £22,000 per MW

Onshore wind estimated OPEX is £22,000 per 1MW turbine.

Source: Department for Business, Energy and Industrial Strategy. (2020). Onshore Wind and Solar PV Costs Review. Newcastle upon Tyne: WSP.

[R26] Wind Capacity Factor in NI: 26%

A wind capacity factor on the island of Ireland of approximately 26%.

Source: EirGrid and SONI. (2024). Annual Renewable Energy Constraint and Curtailment Report 2023. Belfast: EirGrid and SONI.

[R27] New Solar Installation: £672.50/kW

A price range of £615-730/kW capital install cost, moving forward with a midpoint cost value of £672.50/kW.

Source: Department for Business, Energy and Industrial Strategy. (2020). Onshore Wind and Solar PV Costs Review. Newcastle upon Tyne: WSP.

[R28] Solar OPEX Cost: 1% CAPEX

Determining a precise OPEX cost for solar panels has been challenging, therefore an assumption [A11] of 1% has been used based on data provided by solar PV supplier Lumify Energy.

Source: Lumify Energy. (2024, March 29). Cost of Solar Panels in the UK: Running a Solar Farm. Retrieved from Lumify Energy: https://lumifyenergy.com/blog/cost-of-solar-panels/

[R29] Solar Capacity Factor in NI: 12%

The solar capacity factor in NI can be extrapolated from Figure 24 in "The viability of green hydrogen production in Northern Ireland" to provide an average capacity factor of 12%.

Source: EirGrid and SONI. (2024). Annual Renewable Energy Constraint and Curtailment Report 2023. Belfast: EirGrid and SONI.

[R30] LOHC Price: £1.37/kg

Conversion to LOHC - €0.41/kg; LOHC export costs - €0.10/kg; Re-conversion from LOHC - €1.10/kg. The above total converted to GBP. The cost does not consider movement of LOHC to the desired location as this is subject to distance.

Source: Collis, J., & Schomäcker, R. (2022). Determining the Production and Transport Cost for H₂ on a Global Scale. Berlin: Technische Universität Berlin.

[R31] Levelised Cost of Hydrogen Storage for Compressed Gaseous Above-Ground Storage: £0.26/kg

$0.33/kg converted to GBP. The LCHS is assumed to include the cost of all required infrastructure to facilitate the storage [Assumption A12].

Source: Abdin, Z., Khalilpour, K., & Catchpole, K. (2022). Projecting the levelized cost of large scale hydrogen storage for stationary applications. Energy Conservation and Management.

[R32] Levelised Cost of Hydrogen Storage for Methanol Conversion: £1.78/kg

$2.25/kg converted to GBP. The LCHS is assumed to include the cost of all required infrastructure to facilitate the storage [Assumption A12].

Source: Abdin, Z., Khalilpour, K., & Catchpole, K. (2022). Projecting the levelized cost of large scale hydrogen storage for stationary applications. Energy Conservation and Management.

[R33] Levelised Cost of Hydrogen Storage for Ammonia Conversion: £2.77/kg

$3.51/kg converted to GBP. The LCHS is assumed to include the cost of all required infrastructure to facilitate the storage [Assumption A12].

Source: Abdin, Z., Khalilpour, K., & Catchpole, K. (2022). Projecting the levelized cost of large scale hydrogen storage for stationary applications. Energy Conservation and Management.

[R34] Hydrogen Transport via Road: £1.23/kg

Road transport costs are assumed to be inclusive of the necessary transport equipment such as hydrogen tube trailers. Linked to Assumptions A14/A15.

Source: DESNZ. (2023). Hydrogen transport and storage infrastructure. London: DESNZ.

[R35] Hydrogen Transport via Pipeline: £0.17/kg

The pipeline costs are relative to repurposing existing pipelines, avoiding the expense of new network construction. Linked to Assumption A16.

Source: DESNZ. (2023). Hydrogen transport and storage infrastructure. London: DESNZ.

[R36] On-Site Refueller CAPEX Cost: £1,975,000

Due to the lack of volume related pricing, a conservative $2.5million will be used to cover the lifetime of the refueller of 25 years, and converted to GBP.

Source: https://www.cranfield.ac.uk/press/news-2023/how-a-uk-hydrogen-car-industry-could-cut-fuel-costs-and-carbon-emissions#:~:text=But%20hydrogen%20refuelling%20stations%20are,for%20an%20EV%20charging%20station.

[R37] Cost per Acre of Land in NI: £14,736.00

Linked in Assumption A18, that land will be agricultural.

Source: Cullen, L. (2025). Farmland prices exceed £20k in NI county for first time. Belfast: BBC News.

[R38] Acres Required per MW Electrolysis: 6

Acreage estimate range is 5-7 acres per MW of electrolysis.

Source: National Renewable Energy Laboratory. (2023, May). Green Hydrogen: A Briefing for Land Managers. Retrieved from National Renewable Energy Laboratory: https://www.nrel.gov/docs/fy23osti/83885.pdf

[R39] Acres Required per MW Wind: 21

The acreage required per MW of wind is estimated to be 2-40acres, calculations will be based on the midpoint of 21 acres per MW of wind installed.

Source: Benn, T. (2023, September 18). Land Required for a Wind Farm – What Landowners Should Know. Retrieved from Lumify Energy: https://lumifyenergy.com/blog/land-required-for-a-wind-farm/#:~:text=While%20it's%20being%20constructed%20and,overall%20acreage%20you'd%20need.

[R40] Acres Required per MW Solar: 5

The acreage required per MW of solar is estimated to be 25 acres per 5MW, therefore 5 acres per 1MW.

Source: Benn, T. (2024, February 02). Solar Farm Land Requirements: What Landowners Should Know. Retrieved from Lumify Energy: https://lumifyenergy.com/blog/solar-farm-land-requirements/#:~:text=Generally%2C%20a%20solar%20farm%20requires,be%20on%20the%20safe%20side.

[R41] Planning Permission Cost: £322,915.00

For planning permissions in Northern Ireland for plant and machinery, there is an associated planning fee, if the site exceeds 5 hectares, of £21,700, and an additional £129 for each 0.1 hectare in excess of 5 hectares, subject to a maximum total of £322,915. Based on the hectarage required for a wind installation to feed a 10MW electrolyser, the planning fee is approximately £308,000. To be conservative, the maximum planning fee of £322,915 will be applied to the model.

Source: Department for Infrastructure. (2025, April 01). Planning Fees. Retrieved from Department for Infrastructure: https://www.infrastructure-ni.gov.uk/sites/default/files/2025-03/planning-fees-explanatory-notes-for-applicants-apr2025.pdf

[R42] EIA Costs: £12,924.00

Based on the assumption A18 that this will be an agricultural site, there will likely require an Environmental Impact Assessment (EIA) at an additional cost of £12,924.

[R43] Compression CAPEX Costs: €1.75/kg H₂

We are adopting a conservative approach, setting the CAPEX cost for hydrogen compression at €1.75/kg. This figure is derived from the €0.9 - €1.75/kg range used in energy environmental modelling by ETSAP (ETSAP, 2014). €1.75 converted to £1.38 based on current conversion at time of modelling.

Source: ETSAP. (2014). Hydrogen Production & Distribution. ETSAP.

[R44] Oxygen Sales Price: £180.96/Tonne

Based on the $243/Tonne sale price for Spain - No UK examples available. Converts to £180.96/T based on exchange rate at time of reporting.

Source: IMARC. (2025). Bulk Oxygen Prices, Trend, Chart, Demand, Market Analysis, News, Historical and Forecast Data Report 2025 Edition. Brooklyn: IMARC.

[R45] Battery Storage Price: £158/kW

Based on midpoint of $100-300/kWh price converted to GBP based on exchange rate at time of reporting.

Source: Ritar Power. (2024, October 28). 50MW Battery Storage Cost: An In-depth Analysis. Retrieved from Ritar Power: https://www.ritarpower.com/industry_information/50MW-Battery-Storage-Cost-An-In-depth-Analysis_286.html#:~:text=On%20average%2C%20the%20cost%20of,%245%20million%20and%20%2415%20million.

[R46] Battery Storage OPEX: 2% Battery Storage CAPEX

Assumption [A23] made on unknown OPEX.

Source: Internal assumption due to lack of available data.

[R47] Battery Storage Design Life: 12 Years

Currently referenced as 10-12 years, but expected to increase as advancements are made in the market.

Source: Eco Affect. (2024, May 20). Life Expectancy of Battery Storage Systems. Retrieved from Eco Affect: https://ecoaffect.org/battery-storage/life-expectancy-battery-storage-systems/

[R48] Hydrogen Fuel Cell Price: £29/kW

UK firm showcase groundbreaking price of £29/kW for hydrogen fuel cells.

Source: Bramble Energy. (2025, July 21). Bramble Energy achieves even further groundbreaking fuel cell cost reduction. Retrieved from Bramble Energy: https://www.brambleenergy.com/resources/bramble-energy-achieves-even-further-groundbreaking-fuel-cell-cost-reduction/

[R49] Hydrogen Fuel Cell OPEX: 3% Hydrogen Fuel Cell CAPEX

Assumption [A24] made on unknown OPEX.

Source: Internal assumption due to lack of available data.

[R50] Fuel Cell Design Life: 5 Years

Just over 40,000 hours.

Source: European Commission. (2014). Final Report Summary - STAYERS (STAYERSStationary PEM fuel cells with lifetimes beyond five years). Netherlands: NEDSTACK FUEL CELL TECHNOLOGY BV.

Disclaimer: This model is for informational purposes only and should not be used as a basis for investment decisions.

*This data was sourced from Renewables Ninja, using hourly data from 2019 for a site in Northern Ireland located at coordinates 54.62459240596287 latitude and -5.743422807297186 longitude, showing a wind capacity factor of 43.8% and a solar capacity factor of 11.4%.*