Production cost and fuel qualification lead to different choices
The Danish renewables-and-grid reference costs $1,687.82/t under annual matching and fails the model's renewable-fuel screen. The islanded hybrid costs $1,944.77/t before any competitive award and passes that screen under its hourly-matching assumptions. The comparison combines power-system design with different qualification assumptions.
Choosing between them requires a clear view of the buyer's needs. A competitive grant can improve producer economics. Customer acceptance also depends on power sourcing, carbon credentials and contract terms.
Compare the complete production design
Connect the design to the commercial decision
The production design
- Power and hydrogenSupply shape, electrolysis and storageHourly hydrogen supply
- Carbon and synthesisDelivered CO₂ and the methanol loopMethanol output
The commercial decision
- Production economicsAssets, operating costs and supportGross and net cost
- Price and buyer evidenceFinancing, contract assumptions and customer alternativesRequired selling price
Compare the production design, its required revenue and the customer's compliance proposition.
A power offer affects more than the energy bill. It changes generation and storage requirements, hydrogen availability and the feed reaching synthesis. Carbon supply then adds its own cost and qualification questions. The useful comparison connects these choices before asking what a tonne of methanol must earn.
The electricity bill can become an asset commitment
Biogas CO₂; owned renewables with grid top-up; annual matching; fails the RFNBO screen for 2030; steady operating mode.
What builds the production cost?
USD/t methanol- Capital
- Fixed O&M
- Purchased power
- Delivered CO₂
- Water
- Replacement
- Subtotal / total
Scroll across to see all cost components.
Production cost under the stated scenario assumptions. Required selling price also reflects financing and the sponsor's target return.
The selling price required to achieve the sponsor’s target return, including modeled support.
In the Danish grid-backed design, purchased power contributes $778.65/t and capital $585.71/t. Switch to the hybrid and the purchased-power line disappears, while capital reaches $1,319.91/t. Owned generation and storage put the cost of electricity into the investment budget.
These structures call for different commercial work. One needs scrutiny of bought-power prices and terms; the other needs confidence in the combined asset budget and the output those assets can sustain. The full Excel workbook lets a team replace the reference assumptions with its own power arrangement, equipment costs and plant scale, then follow the consequences through the same calculation.
Separate producer support from customer value
Production cost before incentives. The scale stays fixed across views.
Two Danish designs: production cost and award potential
USD/t methanolSelect a cost category to see its value in every design.
Production cost only; no incentives deducted.
Support assumptions
- Both Danish designs · no direct statutory producer payment
Both baselines exclude direct statutory producer payments and competitive capital awards. The grant illustration applies to the hybrid design.
Both production-cost calculations exclude FuelEU buyer-compliance value, which is assessed through the customer's economics.
Before support, the grid-backed design is cheaper. If the hybrid receives the illustrative capital grant, its net cost falls from $1,944.77/t to $1,647.12/t, slightly below the grid-backed design’s $1,687.82/t. The grant funds part of the same physical design. Both baselines assume zero direct statutory producer payments.
The model also calculates the selling price needed to meet the sponsor's return requirement. Before a competitive award, it is $1,838.34/t for renewables with grid top-up and $2,284.30/t for the hybrid. These calculated requirements provide a basis for testing buyer offers.
Renewable fuels of non-biological origin, or RFNBOs, must meet production and emissions requirements. The grid reference uses annual matching and has a modeled policy-view intensity of 40.08 gCO₂e/MJ. It fails the model's RFNBO screen for operation beginning in 2030. EU rules allow qualifying grid-connected production under the relevant sourcing and correlation conditions. Testing that option would require different power and operating assumptions, followed by a fresh economic calculation.
The buyer illustration assumes 100% intra-EU voyage coverage, a penalty-parity valuation based on avoiding FuelEU penalties, and a non-discounted posted methanol reference of €915/t. On this basis, the grid reference has a $1,081.58/t buyer-value ceiling, below its required price. The hybrid's $2,613.20/t ceiling exceeds its $2,284.30/t required price. This headroom identifies a customer proposition to test.
Methanex's posted prices provide references for contracts that include customer discounts. Test the illustration against negotiated fuel prices, the buyer's voyage and fuel allocation, and pooling alternatives. Delivery terms and the division of compliance benefits between buyer and supplier determine how much value reaches the producer.
Test the project with and without a grant
The Innovation Fund illustration in Figure 2 assumes a grant equal to 25% of project capex. Its $297.64/t effect on net production cost differs from its $450.39/t effect on required selling price: the latter falls from $2,284.30/t to $1,833.91/t in the separate sponsor cash-flow calculation. Tax, timing and financing make these different measures. Each result already includes the grant's effect on that metric.
With the grant, the hybrid’s required price is close to the grid-backed design’s, while retaining its different compliance proposition. That makes the award worth pursuing, but leaves a larger revenue requirement if the application fails. The no-award case still needs a credible commercial path.
The outlined negative bar and hollow marker show if awarded, using the same physical design. The 25% grant is an illustrative scenario assumption. Actual awards under the competitive Innovation Fund framework depend on eligibility, selection and relevant-cost assessment. Payment milestones and contract terms also need confirmation.
The model assumes payment at commercial operation, discounts the pre-tax grant in net cost and taxes it in the required-price calculation. The illustrative grant falls within the modeled award cap.
A different carbon source creates a different cost problem
Production cost across three complete designs
USD/t methanolSelect a cost category to see its value in every design.
Production cost only. No incentives are considered.
The prospective Chile wind/DAC design has a $2,099.23/t gross cost, including $714.00/t for delivered carbon under the model's supply-price assumption. The corresponding carbon contribution in each Danish biogas case is $112.98/t. This forward-looking case tests the cost of supplying a wind-powered plant with carbon captured from the air; commercial-scale availability and delivered terms need project-specific evidence.
Power configuration, scale, carbon source and finance differ together across these complete projects. Isolating a country or carbon-source effect would require holding the other assumptions constant. Assess the carbon supply's delivered cost, specification and availability alongside the energy offer.
Storage connects hydrogen production with synthesis
Biogas CO₂; owned renewables with grid top-up; annual matching; fails the RFNBO screen for 2030; steady operating mode.
Hydrogen production and synthesis feed
t H₂ per hour- Hydrogen produced
- Synthesis feed
- Hydrogen produced
- 2.21 t H₂ per hour
- Synthesis feed
- 2.28 t H₂ per hour
Hydrogen buffer at the end of each hour
t H₂- Closing inventory
- Closing inventory
- 2.59 t H₂
Hours 4009 to 4056 of the reference year show an operating example, with flow and inventory on their own scales. Annual performance requires the full year's operation.
In this selected interval, the hybrid maintains constant synthesis feed while hydrogen production varies. Its buffer absorbs the difference. The grid-backed design has some hours with insufficient feed, despite access to imported electricity. Sustaining the intended operating pattern requires adequate equipment and storage as well as grid access.
These operating results reflect different equipment sizing and storage: 24 hours of nominal hydrogen buffer in the hybrid, versus 16 hours in the grid-backed design. Assessing what those commitments contribute requires a full-year comparison. The workbook follows all 8,760 hours.
For analysts: what the hourly chart includes
Both views use original reference-year hours 4009 to 4056. Production and synthesis feed are tonnes of H₂ in each hourly interval; closing buffer inventory is tonnes of H₂ on a separate scale. The grid-backed design combines owned renewables with grid top-up.
Annual performance requires the full-year results, including the electricity balance, curtailment and other operating detail in the workbook. Isolating storage's contribution requires a matched-design comparison; support eligibility requires a separate assessment.
Let the sensitivity set the next research priority
Biogas CO₂; owned renewables with grid top-up; annual matching; fails the RFNBO screen for 2030; steady operating mode.
What moves net production cost?
USD/t methanolChanges from 1687.82 USD/t methanol. Each assumption changes separately.
Left: lower cost or price. Right: higher cost or price. One-sided results retain their direction.
Each assumption is tested separately against this design’s net-cost baseline. The bars show calculated responses, including one-sided and asymmetric effects.
For the grid-backed design, a 20% bought-energy price shift changes net cost by $154.31/t. Adding the model's one-sided $85/t biogenic-carbon opportunity cost adds $119.00/t of methanol. Those results make both the power terms and the carbon supplier's alternative uses worth understanding.
For the hybrid, a 20% capex shift moves net cost by $283.74/t. The synthesis-capacity tests change the 100 kt/year loop to 50 or 200 kt/year while holding power assets and electrolyzer capacity fixed. Both changes raise cost in the hybrid and Chile cases as the balance between synthesis and hydrogen supply changes. A whole-project scale study would require coordinated resizing. Chile also shows a $214.20/t response to a 30% delivered-CO₂ price shift.
The sensitivity results show which assumptions deserve further evidence. They measure responses to specified changes. The full workbook carries eleven driver families, including specific energy, availability and stack life. Use the wider set to challenge a shortlist before refining inputs that have little influence on the decision.
For analysts: model boundary, financing and commercial assumptions
The boundary is plant-gate methanol in real 2026 USD. The model assumes construction starts in 2027, with commercial operation in 2030; the earlier capital draw and commissioning period change construction interest and discounted capital cost across the designs. Terminal, distribution and vessel-specific implementation costs require separate assessment. Dispatch uses one documented reference year. Hydrogen, carbon and regional assumptions can include declared proxies; Sources_Audit and Evidence_Register record their basis. Renewable-fuel eligibility and carbon-accounting treatment require project-specific review.
The tornado measures changes in net cost. Each test changes one assumption, and its result applies independently; one-sided and both-positive outcomes are retained. The shifts specify test sizes, with no probabilities assigned. Eligible statutory support depends on the project meeting its conditions. Competitive awards and buyer-compliance value are assessed separately from the producer's baseline cash flow. The Chile reference design assumes zero H2Global contract support.
Required price uses linear sponsor tax with immediate loss use. The separate lender view carries losses forward without an 80% limitation. Working capital, decommissioning and salvage are excluded.
Put your own project through the workbook
The e-Methanol Excel model includes 16 prepared designs plus CUSTOM, editable assumptions, the full operating year and scenario comparisons. Follow your choices into required price, cash flows, equity returns and debt coverage through the end of support. The package includes a technical guide, quick-start guidance and documented sources.
Bring the power terms, carbon-supply proposition and investment assumptions your team must defend. Use the workbook to establish which alternatives merit deeper work. CovalentIQ can also help test those assumptions and identify the customer evidence needed to assess commercial terms.
Explore the methanol model or discuss your project.
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