Market Size, Demand & Growth

Carbon capture, utilisation and sequestration went from a policy talking point to a fundable industry in the space of about five years. Independent market studies put the 2025 global market at roughly $3.9 billion to $7.9 billion depending on scope, with a consensus compound annual growth rate between 18% and 25% through the early 2030s (market.us, 2025). One widely cited projection has the carbon capture and sequestration market reaching $26.3 billion by 2035 at a 21.1% CAGR, with North America holding about a 39.5% share (market study, 2025).

The wide range in those figures is not sloppiness. Analysts disagree on whether to count only capture equipment, or the full value chain of capture, transport, storage and utilisation. A business plan that quotes a single number without saying which definition it uses looks naive to a specialist reader. The number that actually moves a lender is not the headline market size; it is the volume of capturable CO2 within economic transport distance of your site and the price per tonne you can realise on it.

Demand is driven by three forces that a plan should name explicitly. First, hard-to-abate emitters such as cement, steel, ammonia, ethanol and gas processing have no cheap alternative to capture if they want to keep operating in a carbon-constrained world. Second, the US Section 45Q tax credit and Canada's CCUS Investment Tax Credit have turned captured tonnes into a bankable cash flow. Third, a voluntary market of corporate buyers is paying a premium for durable carbon removal, which is what makes higher-cost direct air capture viable at all. Operators such as ExxonMobil, Shell plc and Chevron Corporation are building at industrial scale, while developers like BKV Corporation and California Resources Corporation are commercialising dedicated storage. The whitespace for a startup sits between them: a focused capture retrofit, a regional storage hub, or a removal-credit venture that the majors are too large to bother with.

Geography decides the project

CCS is one of the most location-dependent businesses there is, and a plan that treats site as an afterthought reads as inexperienced. Two geographic facts drive economics more than almost anything else. The first is subsurface geology: whether there is a deep saline formation or depleted reservoir with the porosity, permeability and seal integrity to hold injected CO2 for centuries. The US Gulf Coast, the Illinois Basin, and the UK and Norwegian sectors of the North Sea are favoured precisely because their geology has been characterised over decades of oil and gas work. The second is proximity to CO2 sources and existing pipelines. A facility within roughly 50 miles of an emitter or an existing CO2 pipeline has materially better economics than one that must build transport from scratch, because transport is pure cost with no incentive attached. In the US, states with Class VI primacy such as North Dakota, Wyoming and Louisiana can also review storage permits directly, which shortens the pre-revenue timeline and is itself a location advantage worth naming in the plan.

Questions Founders Ask First

These are the questions that come up in almost every early conversation with a carbon capture founder, answered in the plainest terms before we get into the plan itself.

Is carbon capture and sequestration actually a business, or a subsidy scheme?

It is a business whose margin is unusually dependent on policy. The core transaction is simple: you capture a tonne of CO2, you store or use it permanently, and someone pays you per tonne. The per-tonne payment today comes from a mix of the 45Q credit, government cluster contracts in the UK, and voluntary removal buyers. A plan that treats these as permanent guarantees is fragile; a plan that models what happens if credit values fall, and shows the project still clears a hurdle rate, is fundable.

Do I need to own a well or a factory to start?

No. Many of the most capital-efficient entrants are service or aggregation plays. A storage developer contracts CO2 from several nearby emitters and takes on the injection and monitoring. A capture integrator licenses solvent or adsorption technology from a provider such as Svante and installs it on a client's stack. You do not need to invent the chemistry; you need to assemble the site, the permit, the offtake and the financing into a package a lender will underwrite.

How big does a first project have to be?

Small enough to permit and finance, large enough to matter. A common first-project scale is 100,000 to 300,000 tonnes of CO2 per year. At the $85 per tonne 45Q rate, 250,000 tonnes represents about $21 million a year in gross credit value, which is enough to interest a project lender while staying inside what a first-time developer can realistically build and monitor.

What is the single biggest risk?

Timeline. The gap between spending money on site characterisation and earning your first tonne of revenue can run several years, dominated by the Class VI permit in the US or a storage licence and appraisal in the UK. Ventures fail in this valley, not because the technology does not work, but because they run out of cash before first injection. The plan's job is to fund that valley.

Who buys what I capture?

This is the question that reveals whether a founder has a business or a hobby. There are three kinds of buyer, and a credible plan names at least one specifically. The first is the tax-equity or credit-transfer buyer who purchases your 45Q credit for cash. The second is an industrial CO2 offtaker who wants the gas itself for enhanced oil recovery, beverage carbonation, concrete curing or synthetic-fuel feedstock. The third is a corporate carbon-removal buyer, the constituency behind Microsoft's widely reported purchases from Occidental's 1PointFive, who pays a premium for durable, verifiable removal. Which buyer you build around determines your whole model: credit-transfer suits a point-source retrofit, offtake suits a location near demand, and removal credits suit a higher-cost direct air capture venture with a premium story to tell.

Startup Capital & Funding Routes

Full-scale CCS facilities cost hundreds of millions of dollars, but that is not what a founder raises first. The realistic startup figure to get a venture from concept to a financeable, permit-ready position is $250,000 to $2.5 million in the US, or roughly £200,000 to £2 million in the UK. This is development capital: the money that buys you a defensible site, a permit application, a technology decision and an offtake structure, so the much larger construction round becomes bankable.

Where the development budget goes

• Feasibility, site characterisation & FEED study: $120K–$600K (£95K–£480K). Subsurface data for storage; source and concentration data for capture.
• Class VI permit or storage-licence application & MRV plan: $150K–$800K (£120K–£640K). The single largest pre-revenue line for a storage venture.
• Capture pilot or skid (amine or solid-adsorption): $300K–$1.2M (£240K–£960K), if you are proving capture rather than only storing.
• Engineering, legal & offtake structuring: $80K–$300K (£64K–£240K). CO2 supply agreements, storage leases, 45Q transfer terms.
• Insurance, financial assurance & 12 months working capital: $100K–$400K (£80K–£320K). Long-term liability cover is a permit condition, not an optional extra.

Funding routes for the development stage

Because CCS sits between climate impact and hard infrastructure, the funding stack is broader than a typical startup. Founders commonly combine climate-focused venture capital and angel money for the earliest development spend, non-dilutive government grants once a project is defined, and project debt once permits and offtake de-risk the build. In the US, the SBA 7(a) programme covers up to $5 million and can fund the corporate and equipment layer of a smaller capture venture, while the US Department of Energy demonstration and loan programmes cost-share larger decarbonisation projects. In the UK, the Start Up Loans scheme (up to £25,000 at 6% fixed) seeds the corporate entity, while cluster-level support flows through the Track-1 and Track-2 business models. Whatever the mix, lenders and grant assessors read the same thing first: a five-year model showing per-tonne revenue clearing per-tonne cost with margin to spare.

It helps to think of the capital in stages, because investors do. The development round described above buys you a permit-ready, offtake-backed project. Only then does the far larger construction round, which for a real storage well or capture train runs into the tens or hundreds of millions, become financeable on project-debt terms rather than expensive equity. Founders who try to raise the whole amount up front, before the permit and offtake exist, almost always fail; the risk is too concentrated. Sequencing the raise, and showing in the plan exactly what each tranche pays for, is what separates a fundable CCS venture from a science project with a pitch deck.

Federal & Public Funding Programmes

More than any consumer business, a CCS plan lives or dies on how well it uses public incentives. These are the programmes underwriters expect you to name correctly, with the numbers that make them worth modelling.

The strategic point most plans miss: 45Q is transferable. Under current rules a developer can sell the credit to a third party for cash, which lets a project without large tax liability still monetise the incentive. That single mechanism is often the difference between a model that funds itself and one that stalls. Our Research + Content and Bespoke packages build the 45Q build-up, construction-start eligibility and transfer assumptions directly into the forecast, because investor-ready market research and content is where these plans are usually weakest.

How CCS Ventures Make Money

Revenue in this business reduces to one equation: tonnes captured or stored × value per tonne. Everything else in the model is a cost that eats into the spread between them. Get both variables specific to your project and the plan writes itself; leave them vague and no lender will move.

Value per tonne comes from three stackable sources. The 45Q credit pays $85 for saline geologic storage and up to $180 for direct air capture. CO2 offtake, where a buyer pays for the gas itself for use in enhanced oil recovery, beverages, concrete curing or synthetic fuels, adds a second stream. Voluntary removal credits for durable storage trade anywhere from $100 to over $1,000 per tonne depending on permanence and buyer, which is what supports premium direct air capture ventures. Cost per tonne runs from roughly $30 to $60 for concentrated point sources up to $600 to $1,000 for today's direct air capture, per publicly stated Climeworks figures.

A worked example

Consider a point-source retrofit on an ethanol plant, one of the cleanest CO2 streams available. Capturing 250,000 tonnes per year at the $85 per tonne 45Q rate generates about $21.25 million in annual credit value. Subtract capture energy, compression, transport to the storage site, monitoring and financing, and a project targeting a 15% net margin nets roughly $3.2 million a year. That $3.2 million, not the $21 million headline, is what a lender or a 45Q-transfer buyer underwrites, because it is what survives after real costs. A plan that shows this arithmetic transparently, with sourced capture-cost assumptions, reads as the work of someone who has actually run the model.

Margins vary widely by model. Capital-light storage-as-a-service, where the developer charges emitters a tolling fee to inject their CO2, can clear a higher margin than an integrated capture-and-store build because it avoids the capture capex. That is exactly the kind of trade-off your revenue section should lay out rather than assuming a single blended figure.

Contract structures that make revenue bankable

Lenders do not finance a spreadsheet of projected tonnes; they finance contracts. The three that matter most in a CCS plan are the CO2 supply agreement with the emitter, the storage lease or tolling agreement, and the mechanism that turns the incentive into cash. On the last point, the transferability of the 45Q credit changed the game: a developer with little tax appetite can sell the credit to an investment-grade buyer, often at a modest discount, and book the proceeds against the project. A plan that names a plausible credit-transfer counterparty and models the discount reads as far more mature than one that simply assumes the full $85 flows in. Term length matters too. A 12-year 45Q claim window paired with a multi-year offtake gives a lender a visible repayment horizon; a project relying on spot-priced voluntary credits alone looks speculative by comparison.

It is also worth modelling downside explicitly. What happens to the project if credit values are cut, if a construction-start deadline is missed, or if a single anchor emitter closes? A plan that shows the venture surviving a 20% haircut to per-tonne value, because it diversified across two emitters and layered CO2 offtake on top of the credit, is exactly the kind of stress test a project-finance committee runs before it commits. Building that resilience into the numbers is the difference between a plan that gets read and one that gets funded.

Permits, Storage Licences & Legal

Permitting is where CCS plans are most often thin, and where a specialist reader looks hardest. The section below is keyword-specific on purpose: generic "obtain relevant licences" language is a red flag in this industry.

United States

• EPA Class VI Underground Injection Control permit for permanent geologic storage, administered by the US EPA or by primacy states such as North Dakota, Wyoming and Louisiana. Historically 2–6 years; site characterisation, well integrity and monitoring drive the timeline.
• Section 45Q compliance, including secure-geologic-storage documentation and the lifecycle analysis needed to claim the credit.
• MRV plan (measurement, reporting and verification) approved by the EPA under Subpart RR for storage claims.
• Long-term financial assurance for post-injection site care, a permit condition that many plans forget to budget.
• Pipeline and transport permitting if CO2 moves off site; proximity to an existing pipeline materially improves project economics.

United Kingdom

• CO2 storage licence and lease from the North Sea Transition Authority and The Crown Estate; more than 20 storage licences are in development and a second licensing round opened in late 2025.
• Industrial Carbon Capture and Track-1/Track-2 business models administered by DESNZ, the route through which the £21.7B cluster funding reaches projects such as HyNet and the East Coast Cluster.
• Environmental permits from the Environment Agency and interaction with the UK Emissions Trading Scheme.
• Development consent for the physical infrastructure, with appraisal-to-permit spanning several years offshore.

Canada (a third jurisdiction worth naming)

Canada's refundable CCUS Investment Tax Credit is only available in designated jurisdictions with fully developed storage regulatory frameworks, currently Alberta, British Columbia and Saskatchewan. Alberta adds a 12% grant through the Alberta Carbon Capture Incentive Program on top of the federal credit. If your plan contemplates Canadian expansion, it must show you understand that the incentive follows the province, not just the country.

The permitting-to-revenue timeline lenders want to see

Because the gap between spending and earning is the defining risk in this business, the plan should lay out a clear month-by-month path rather than a vague promise. A realistic storage-project sequence looks like this: months 1 to 8, feasibility and site characterisation using available subsurface data; month 9, submit the Class VI permit application with the modelling and monitoring plan; months 9 to roughly 36, permit review, well construction and testing, running in parallel where possible; around month 40, first injection and first revenue; and from there, the 12-year 45Q claim window begins. Every month in that pre-revenue window has a cash cost, and every month of it must be funded by the development round. A plan that maps its raise against this timeline, showing runway extending safely past first injection, is doing the one thing a project lender needs before anything else.

CCS Terms Investors Expect You to Know

Using these terms precisely signals to a specialist reader that you have done the work. Misusing them does the opposite.

• Point-source capture: removing CO2 from a concentrated industrial exhaust stream at the emitter, where concentrations are high and cost per tonne is low.
• Direct air capture (DAC): extracting CO2 from ambient air at roughly 420 parts per million, energy-intensive and costly today but valued for durable removal credits.
• Sequestration / geologic storage: permanent injection of CO2 into deep saline formations or depleted reservoirs, monitored to confirm it stays put.
• Class VI well: the US EPA well category authorised specifically for permanent CO2 storage, distinct from Class II enhanced-oil-recovery wells.
• MRV: measurement, reporting and verification, the evidence chain that proves stored CO2 remains stored, and a prerequisite for both 45Q and removal credits.
• Offtake agreement: a contract in which a buyer commits to purchase captured CO2 or removal credits, the document that turns a project into a bankable one.
• Tolling / storage-as-a-service: a model where the developer charges emitters a per-tonne fee to inject and store their CO2, avoiding capture capex.

Three Ways to Structure the Business

Most founders default to "we will build a capture plant," but that is only one of three viable models, and rarely the most capital-efficient first move. The plan should state which one you are pursuing and why, because they have different capex, different risk and different buyers.

The comparison matters because a lender's first question is which model, and the second is why you can win in it against the majors. A regional storage hub that aggregates two or three mid-sized emitters is a defensible startup position precisely because it is too small for ExxonMobil to chase and too capital-intensive for the emitters to build alone.

There is also a fourth angle that sits alongside these three rather than replacing them: the technology and services layer. Not every entrant needs to own tonnes. Companies such as Svante license solid-sorbent capture technology, and a growing set of firms provide site characterisation, MRV software, permitting support and measurement services to the developers who do own the projects. For a founder with deep technical or subsurface expertise but limited capital, a services play can reach revenue years faster than a storage project, and can later fund a move into ownership. The plan should be honest about which of these you are, because the financials, the team and the risk profile of a services business look nothing like those of a capital project.

Mistakes That Sink CCS Plans

Across capture and storage plans we have reviewed, the same avoidable errors turn up again and again.

• Leading with technology, not the deal. Investors fund a bankable offtake and revenue contract, not a diagram of an absorber column. Put the money story first.
• Underbudgeting the permit valley. A Class VI permit or UK storage licence can run several years. Plans that assume revenue in year one, before first injection, lose credibility instantly.
• Modelling 45Q or the Canada ITC without the fine print. Construction-start deadlines, eligibility thresholds and jurisdiction rules all constrain the credit. Quoting the headline rate alone is a tell.
• Treating MRV as an afterthought. Measurement, reporting and verification is a real, recurring cost and a hard permit condition. Lenders scrutinise it; hobby plans ignore it.
• Confusing DAC and point-source economics. Assuming a direct air capture cost curve for a point-source project, or vice versa, produces a model no specialist will trust.

Sample Business Plan Preview

Here is an extract from a carbon capture and sequestration plan written by our team, so you can see the level of specificity a fundable plan carries:

What's in the Template

Every Avvale business plan template comes pre-structured for your industry. For carbon capture and sequestration, that means the sections a project lender and a grant assessor actually read:

• Executive Summary - the deal in 60 seconds: model, volume, per-tonne value, and raise ask
• Company & Model Overview - point-source, storage-as-a-service or removal, and why you chose it
• Market & Policy Analysis - market size by scope, plus the 45Q, cluster and ITC context that sets your revenue
• Source & Offtake Analysis - CO2 supply, concentration, and the buyers or credit-transfer counterparties
• Competitive Positioning - where a focused venture wins against ExxonMobil, Shell, BKV and the majors
• Operations & MRV Plan - capture, transport, injection and the measurement-reporting-verification chain
• Permitting Timeline - Class VI or storage-licence milestones mapped to the cash runway
• Management Team - the subsurface, engineering and commercial expertise lenders expect

The optional Financial Forecast add-on (included in our $300/£250 and $1,000/£800 packages) provides a five-year Excel model with the per-tonne revenue build, capture-cost assumptions, 45Q and grant treatment, income statement, cash flow, balance sheet, break-even analysis and the development-capital requirement. You can also start from our free business plan template and upgrade later, or explore a related bespoke business plan if you need the full done-for-you build. Founders in adjacent clean-energy niches also use our renewable energy business plan template.

Frequently Asked Questions