Hydrogen economics: what would make the project work?

Purchased power leads on net cost

The purchased-power design has the lowest net cost in this Texas comparison: $4.70/kg, against $5.33 for owned wind and $6.92 for the solar–wind–battery hybrid. It achieves that position without a 45V hydrogen production credit under the model's carbon-intensity assumptions. Power procurement therefore deserves attention alongside incentive eligibility.

The required selling price is $4.74/kg for purchased power and $4.83/kg for owned wind. That narrow difference depends on an assumed $68/MWh procurement price, built from an earlier power input and an estimated support-loss adjustment. Actual power offers, capital quotations and financing terms could reverse the ranking.

Connect the choices before comparing the economics

A power decision changes the assets you need, when they can produce and how support is assessed. Trace those effects through the project: a saving on purchased electricity may require additional generation and storage investment.

The electricity bill can move into the balance sheet

The Texas PEM hybrid case supplies its own electricity. Capital contributes $6.42/kg to its $8.57/kg gross cost, including the owned solar, wind and battery assets. Assessing this design requires quotations for the complete asset base, alongside the electrolyzer.

The combined assets must produce enough hydrogen to recover their cost. Generation sizing, storage and operating performance determine how much output carries that investment. Improvements here have more scope to change the result than savings on small consumable costs.

Eligible statutory 45V support reduces modeled net cost to $6.92/kg. This scenario assumes construction begins in 2027, before the 1 January 2028 deadline, and the design meets the modeled carbon-intensity conditions. The separate $6.47/kg required selling price meets the sponsor's modeled return with immediate use of tax losses. At that price, the assumed debt structure fails the model's debt-coverage test. Resizing debt would change the equity requirement and needs a fresh financing assessment.

The power offer deserves as much attention as the credit

In the power purchase agreement (PPA) case, purchased electricity contributes $3.09/kg. The design needs much less capital per kilogram than either owned-generation case, but its commercial advantage now depends heavily on the power contract. Its modeled carbon intensity exceeds the 45V ceiling, so the chart includes no hydrogen production credit for it.

The revised PPA assumption is $68/MWh. It includes a $23/MWh modeled adjustment to the earlier $45/MWh input to reflect the assumed loss of qualifying support for new power supply. This assumed procurement price needs validation against actual offers. It lifts the required hydrogen price from $4.03 to $4.74/kg and brings it close to the wind design's $4.83/kg.

Can the quoted power arrangement deliver the price, shape and conditions assumed here? These results compare complete designs; isolating the effect of a PPA or electrolyzer choice requires holding the other assumptions constant. The workbook's 16 prepared designs and custom scenario provide starting points for substituting actual power terms, equipment quotations and project constraints.

Steadier operation has a dependency worth examining

In this two-day excerpt, grid imports supplement PPA delivery and support a much steadier electrolyzer load than the hybrid achieves. Assessing that arrangement requires the hourly delivery shape and permitted grid use, alongside the annual volume and price. The carbon treatment of grid electricity also affects the case.

In the hybrid, battery discharge sustains operation during some hours of falling renewable supply, but load still varies substantially. To assess the storage investment, compare the additional hydrogen produced over the year with the added cost.

The full Excel workbook follows all 8,760 hours, including storage, grid imports and curtailment, with monthly and weekly views. Use the 48 hours here to examine the operating mechanism, then the full year to assess utilization and cost.

The next diligence question changes with the design

For the hybrid, a 20% capex shift moves net cost by $1.38/kg in either direction. A 7.5% electricity-use shift moves it by $0.64/kg. In the PPA case, the ordering reverses: electricity use moves the result by $0.35/kg, versus $0.25/kg for capex.

For the hybrid, we would scrutinize the combined asset budget. For the PPA case, the selected tests give more weight to validating electricity consumption per kilogram, alongside the power contract itself. Both require evidence beyond these three sensitivities.

A 150-basis-point rise in real weighted average cost of capital adds $1.07/kg to the hybrid result, versus $0.21/kg for the PPA. The same financing shift has a different consequence because the asset commitments differ. The full workbook extends the analysis to ten drivers, helping you prioritize the assumptions that could change the decision.

Test the design within the location

The three Texas cases span $4.70–$8.57/kg in production cost before incentives. That spread is a reason to examine configuration within a location before interpreting a country ranking.

Figure 5 opens on production cost before incentives. Across 15 designs in 13 countries, the component mix gives a better starting point than the headline total. Purchased power dominates several PPA cases; capital and fixed operations dominate the owned-generation cases. Those patterns point to different questions for power suppliers, equipment vendors and project developers.

The Canadian case uses islanded wind to meet the modeled Clean Hydrogen Investment Tax Credit conditions, with a $6.98/kg gross production cost. The cost change from the earlier grid-backed PPA case follows the revised plant configuration. Eligible support reduces that cost to $6.38/kg under the modeled conditions. The credit changes how much of the plant's resource and capital cost the project bears.

Use the toggle to compare costs before support, after eligible statutory support, and with a potential award. Solid negative bars show statutory support; outlined negative bars and hollow diamonds add one named award case while keeping the physical design unchanged. The fixed scale makes the reduction visible without changing the apparent size of the plant costs.

The optional award view tests named contract assumptions for selected designs. The illustrative EU Hydrogen Bank awards reduce the Spanish and German cases by about $0.40/kg. The UK contract example below shows why a larger reduction needs to be read alongside the assumed strike, customer receipts and support duration. These cases help assess contract exposure within a project; production costs provide the common starting point across countries.

An award contributes to the project's revenue requirement

The UK wind-powered design has a $5.85/kg production cost before an award. One assumed Hydrogen Allocation Round (HAR) contract reduces its whole-life net cost to $2.43/kg. The project's total required revenue remains $7.02/kg in this example. The conditional view of Figure 5 shows the net-cost effect of those contract terms.

The assumed contract strike is set to the project's own $7.02/kg required selling price, with customer receipts and the reference price assumed at the selected $1.95/kg floor. The modeled top-up is $5.07/kg during the 15-year contract. Actual HAR settlement responds to achieved sales prices and the applicable floor; higher customer receipts would reduce the top-up under this treatment. Discounting that finite support stream over the project life gives the $3.42/kg reduction in net cost.

The project still needs the modeled combination of customer and contract revenue to meet its return requirement. Winning an award, agreeing its terms and meeting the eligibility conditions remain separate commercial tasks. In Excel, the useful questions are how contract duration, reference-price treatment and financing affect the economics and what happens when support ends.

Put your own project through the model

The Green Hydrogen LCOH Excel workbook lets your team work through the 8,760-hour operating year, compare designs and test its own assumptions. Follow the results into required price, financing cash flows and equity returns. Examine debt-service coverage when support ends, then assess how a different debt structure changes the equity requirement. The package includes a technical guide, quick-start guidance and documented input sources.

Bring the power offer you are considering, the asset costs you need to defend and the return assumptions your team uses. CovalentIQ can help frame the alternatives, challenge assumptions and provide clarity on the commercial evidence the numbers leave unresolved.

Explore the hydrogen model.