Search results for: “climate model”
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Offshore wind: levelized costs?
This model estimates the levelized cost of offshore wind at 13c/kWh, to generate a 7% IRR off of capex costs of $4,000/kW and a utilization factor of 40-45%. Each $400/kW on capex adds 1c/kWh and each 1% on WACC adds 1.3 c/kWh to offshore wind levelized costs.
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Fiber optic data transmission costs?
The costs of fiber optic data transmission run at $0.25/TB per 1,000km in order to earn a 10% IRR on constructing a link with $120 per meter capex costs. Capex is 85% of the total cost. This data fiber breaks down the costs of fiber optic data transmission from first principles, across capex, utilization, electricity…
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Floating production systems versus subsea tiebacks: the costs?
This model estimates the line-by-line costs of an FPSO project, across c45 distinct cost lines (in $M and $/boe). We estimate c$750M of cost savings for a tieback, and c$500M of cost savings for a fully subsea development, as compared against a traditional project with a traditional production facility.
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Biogas: the economics?
Biogas costs are broken down in this economic model, generating a 10% IRR off $180M/kboed capex, via a mixture of $16/mcfe gas sales, $60/ton waste disposal fees and $50/ton CO2 prices. High gas prices and landfill taxes can make biogas economical in select geographies. Although diseconomies of scale reward smaller projects?
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Hydrogen storage: the economics?
This model captures the costs of storing hydrogen, which appear to be much higher than storing natural gas. We estimate a $2.50/kg storage spread may be needed to earn a 10% IRR on a $500/kg storage facility, while costs could be deflated to $0.5/kg if nearby salt caverns are available and projects are large and…
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Gas pipelines, CO2 pipelines, hydrogen pipelines?
This model captures the energy economics of a pipeline carrying natural gas, CO2 or hydrogen. It computes the required throughput tariff (in $/mcf or $/kg) to earn a 10% IRR. Hydrogen tariffs must be 2x new gas pipelines and 10x pre-existing gas pipelines. CO2 disposal is more economic at scale.
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Methane reforming: costs of grey hydrogen, costs of blue hydrogen?
This data-file captures the economics of blue hydrogen production via reforming natural gas: either steam-methane reforming or auto-thermal reforming. Costs and operating parameters are compiled from technical papers. Blue hydrogen can be cost-competitive with CCS, while overall costs are most sensitive to gas prices.
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Methanol production: the economics?
This model captures the economics and CO2 intensity of methanol production in different chemical pathways. We find exciting potential for bio-methanol and blue methanol. These are logistically simple substitutes for oil products, but with lower carbon content. Full cost breakdowns can be stress-tested in the data-file.
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Onshore wind: the economics?
The levelized cost of onshore wind is estimated in this economic model, at 5-7c/kWh to generate 5-10% levered IRRs on new wind project costing $1,000-3,000/kW. The model also contains a granular breakdown of wind capex costs, operating costs, and other economic assumptions for wind projects.
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Absorption chillers: the economics?
Absorption chillers perform the thermodynamic alchemy of converting waste heat into coolness. Capex costs of absorption chillers average $600/kW-th and all-in absorption chiller costs run to 6-7 cents/ton-hour, depending on the price of incoming waste heat. This data-file captures the economics of absorption chillers from first principles.
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