Carbon Capture & Section 45Q Lab

Model carbon capture, utilization and storage (CCUS) levelized costs (LCOA), parasitic energy loads, pipeline transport tariffs, EPA Class VI saline injection, Section 45Q tax credits, and project finance senior debt.

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Industry CCUS Presets:
Gross Levelized Cost (LCOA)
$72.45/t
Capture, Pipe & Geologic Storage
Net Monetized 45Q Value
$78.20/t
$85.00 less 8.0% transfer discount
Annual Project EBITDA
$24.98M
Tolling Fee + 45Q less Operating Costs
Supported Senior Debt
$151.7M
Sized at 1.35x target DSCR
Capture Facility Specifications
Ethanol offers lowest capex/energy penalty; DAC qualifies for $180/t credit.
Midstream Pipeline & Saline Storage
Includes EPA UIC injection well operations, seismic monitoring, and PISC trust fund.
Section 45Q & Senior Debt Sizing
Levelized breakdown of capture capex, energy penalty, compression, transport, storage, 45Q credit, and net margin.
Project EBITDA ($M/year) across pipeline transport distances (0 to 200 miles) under varying power supply tariffs.
20-year project cash flows showing statutory 12-year Section 45Q monetization window vs senior debt amortization.
Levelized Cost of Abatement (LCOA) Waterfall
Value Chain Segment Cost ($/tonne CO2) Share of Gross LCOA
Capture Facility Capex (Amortized) $19.35 26.7%
Parasitic Thermal & Electric Energy $12.60 17.4%
Amine Solvents, Chemicals & Water $4.50 6.2%
Capture Facility Fixed O&M $5.70 7.9%
Supercritical Dense Compression (110-150 bar) $8.50 11.7%
CO2 Pipeline Transportation Tariff $3.38 4.7%
Class VI Geologic Saline Storage & MRV $11.00 15.2%
Gross Levelized Cost of Abatement (LCOA) $65.03 100.0%
Less: Net Monetized Section 45Q Credit -$78.20 -120.3%
Emitter Decarbonization Tolling Revenue +$22.00 Commercial Fee
Total Installed Capex: $171.0M
Annual Captured Volume: 900k tonnes/yr
Daily Sequestration: 2,464 tonnes/day
Net LCOA (after 45Q): $0.00/t
Senior Debt Gearing: 88.7%
Sponsor Equity Check: $19.3M
Electricity Price vs Capex on Gross LCOA ($/t)

Evaluates sensitivity of Gross Levelized Cost of Abatement ($/tonne) across electricity supply tariffs and capture facility capex.

Power \ Capex $100/t $150/t $200/t $250/t $320/t
45Q Transfer Discount vs Pipeline Distance on EBITDA ($M)

Quantifies how Section 6418 transfer discount rates interact with pipeline transit distances on annual project cash flow.

Discount \ Miles 25 mi 50 mi 75 mi 120 mi 180 mi
CCUS Project Finance & Section 45Q Mastery Quiz
1. Under Internal Revenue Code Section 45Q as amended by the Inflation Reduction Act, what is the statutory duration during which qualified facilities may claim production tax credits?
2. What causes the substantial parasitic energy penalty observed in amine-based post-combustion carbon capture systems?
3. What is a defining regulatory obligation imposed on operators of EPA UIC Class VI geologic sequestration wells?
4. Under Treasury Regulation §1.45Q-5, what is the statutory lookback window for tax credit recapture in the event of leaked or vented CO2?

Quantitative CCUS Economics & Section 45Q Mechanics

The levelized cost of carbon abatement evaluates the discounted full-chain expenditures spanning source capture separation, supercritical recompression, high-pressure pipeline transit, and sub-surface reservoir injection:

$$\text{LCOA} = \frac{\sum_{t=1}^{N} \frac{\text{Capex}_t + \text{Energy}_t + \text{Solvents}_t + \text{Compression}_t + \text{Pipeline}_t + \text{Storage}_t}{(1 + r)^t}}{\sum_{t=1}^{N} \frac{\text{CO}_2 \text{ Sequestered}_t}{(1 + r)^t}}$$

Where $N$ represents the project economic life, $r$ is the Weighted Average Cost of Capital (WACC), and annual capital recovery factor $\text{CRF} = \frac{r(1+r)^N}{(1+r)^N - 1}$.

Section 45Q Credit Values & Statutory Thresholds
Capture Category Annual Volume Threshold Geologic Saline Sequestration EOR / Commercial Utilization
Direct Air Capture (DAC) 1,000 tonnes CO2/yr $180 / metric tonne $130 / metric tonne
Industrial Facility (Cement, Chemical, Ethanol) 12,500 tonnes CO2/yr $85 / metric tonne $60 / metric tonne
Electric Generating Unit (EGU / Gas & Coal Power) 18,750 tonnes CO2/yr (≥ 75% capture rate) $85 / metric tonne $60 / metric tonne

Frequently Asked Questions

The Levelized Cost of Carbon Abatement (LCOA) measures the full net present value cost per metric tonne of CO2 captured, transported, and permanently sequestered over the operational life of a CCUS facility. It aggregates levelized capture equipment capital expenditures (amortized via the Capital Recovery Factor), parasitic thermal and electrical energy supply costs, chemical solvents, supercritical compression to 110-150 bar, pipeline transport tariffs, and Class VI injection well storage fees.

The US Inflation Reduction Act (IRA) substantially expanded Section 45Q by increasing the credit value from $50 to $85 per metric tonne for point-source industrial capture with dedicated geologic saline storage, and from $35 to $60 per tonne for carbon utilization or enhanced oil recovery (EOR). For Direct Air Capture (DAC), the credit increased to $180 per tonne for saline storage and $130 for utilization. The IRA also lowered annual volume qualification thresholds to 12,500 tonnes for industrial facilities and 1,000 tonnes for DAC, while authorizing direct pay (Section 6417) and transferability (Section 6418).

Post-combustion capture technologies (such as amine-based chemical absorption) require significant thermal energy (typically 2.5 to 3.5 GJ per tonne of CO2) to boil and regenerate the rich solvent in the desorber stripper column, alongside electrical power to drive draft fans and pumps. In natural gas CCGT power plants or cement kilns, this thermal extraction reduces plant net electrical output by 10% to 25%, establishing energy supply pricing as a primary driver of variable operating expenses.

EPA Underground Injection Control (UIC) Class VI permits regulate deep geologic sequestration in saline aquifers or depleted reservoirs to protect Underground Sources of Drinking Water (USDWs). Permitting requires multi-year geologic characterization, seismic baseline modeling, continuous Monitoring, Reporting, and Verification (MRV), financial assurance guarantees for emergency plugging, and a mandatory 50-year Post-Injection Site Care (PISC) liability monitoring period.

Commercial project finance lenders underwrite senior debt against long-term 12-to-15-year Carbon Capture Services Agreements (CCSA) with creditworthy industrial emitters or investment-grade tax credit purchasers. Senior debt is sized to achieve a target Debt Service Coverage Ratio (DSCR) of 1.30x to 1.45x against net Cash Flow Available for Debt Service (CFADS), taking into account Section 6418 transfer discounts (typically 6% to 10%) and statutory 3-year Section 45Q tax credit recapture risk under Treasury regulations.
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