Quick answer: how Canada prices carbon now
Canada's carbon pricing landscape shifted significantly on April 1, 2025, when the federal government removed the consumer fuel charge — the levy that added roughly 17.6 cents per litre to gasoline. That change affects households and small businesses directly. But industrial carbon pricing? Still very much alive. The Output-Based Pricing System (OBPS) continues to apply to large emitters, and the federal excess emissions charge keeps climbing: $95 per tonne in 2025, $110 in 2026, and a scheduled trajectory to $170 per tonne by 2030.
If you run or manage a facility that falls under OBPS or a provincial equivalent, your carbon costs aren't going down. Use Business carbon footprint calculator to map your emissions before diving into compliance planning.
*Editorial note: Last updated March 2026 — confirm charges and program rules with federal and provincial notices before compliance decisions.*
What is OBPS?
The Output-Based Pricing System (OBPS) is Canada's federal framework for pricing industrial greenhouse gas emissions using output-based benchmarks (tonnes CO2e allowed per unit of product). Facilities that emit above their benchmark pay the federal excess emissions charge or use eligible credits; those that beat the benchmark can earn surplus credits. The former federal consumer fuel charge on retail gasoline and heating fuel was removed in April 2025 — but large industrial emitters remain covered by OBPS or an approved provincial equivalent.
Who is covered under OBPS — and who is exempt?
- Typically covered: Large industrial and thermal facilities that emit about 50,000+ tonnes CO2e per year at a single site under the federal system (some provinces set different thresholds for their own programs).
- Often exempt from federal OBPS: Smaller emitters below the threshold; emissions already priced under a provincial system that meets the federal benchmark; and most household / retail fuel after removal of the consumer charge (April 2025) — though provincial rules and industrial obligations still apply.
- Compliance tools: Pay the scheduled excess emissions charge, surrender offset credits where allowed, trade surplus credits, or reduce emissions below the benchmark.
How this relates to your business carbon footprint
OBPS is a compliance cost for covered facilities — not a full corporate Scope 1–3 story. For strategy, reporting, and voluntary goals, model your organisation with Business carbon footprint calculator, then stress-test against the federal price path toward $170/t CO2e by 2030 and your province's credit markets.
What the OBPS actually does
The Output-Based Pricing System is how Canada prices carbon for heavy industry without crushing competitiveness. Instead of taxing every tonne of emissions, OBPS sets output-based standards — emission intensity benchmarks per unit of production for each industrial sector. A cement plant gets a benchmark per tonne of clinker produced. A steel facility gets one per tonne of steel.
Here's the mechanism: if your facility emits more CO2e per unit of output than the benchmark allows, you owe the difference. You can pay the excess emissions charge, surrender federal offset credits, or use surplus credits purchased from facilities that beat their benchmarks. If your facility emits less than the benchmark, you earn surplus credits you can bank or sell to other covered entities.
This design rewards efficiency rather than penalizing production volume. A facility that doubles output while cutting emission intensity below the benchmark actually earns more credits. Coverage generally kicks in at 50,000 tonnes CO2e per year, though some provinces set lower thresholds.
Federal carbon price trajectory: 2023–2030
The scheduled federal price escalation creates a predictable — and steep — cost curve for non-compliant facilities:
| Year | Federal carbon price (CAD/tonne CO2e) | Year-over-year increase |
|---|---|---|
| 2023 | $65 | +$15 |
| 2024 | $80 | +$15 |
| 2025 | $95 | +$15 |
| 2026 | $110 | +$15 |
| 2027 | $125 | +$15 |
| 2028 | $140 | +$15 |
| 2029 | $155 | +$15 |
| 2030 | $170 | +$15 |
A federal benchmark review announced for 2026 could adjust the trajectory or tighten sector benchmarks. Facilities should plan against the published schedule while monitoring the review for signals.
Key takeaway: The consumer fuel charge is gone, but industrial carbon pricing keeps escalating — $95/tonne in 2025 heading to $170/tonne by 2030 — so large emitters still face growing compliance costs.
Provincial systems: a patchwork of approaches
Provinces can replace the federal OBPS with their own systems, as long as they meet the federal stringency benchmark. Several provinces have done exactly that, creating a patchwork of carbon market rules across the country:
| Province | System | Coverage | Price signal (2025) | Credit type |
|---|---|---|---|---|
| Alberta | TIER (Technology Innovation and Emissions Reduction) | Facilities ≥100,000 tCO2e/yr | Headline $95/t; offset credits trading <$20/t | Performance credits, emission offsets |
| Quebec | Cap-and-Trade (linked with California) | Facilities ≥25,000 tCO2e/yr + fuel distributors | Auction clearing ~$45–55 CAD/t | Allowances (auctioned + free allocation) |
| British Columbia | Carbon tax + output-based pricing | Economy-wide carbon tax + large emitter program | $95/t carbon tax rate | BC offset credits |
| Ontario | Federal OBPS applies | Large emitters ≥50,000 tCO2e/yr | $95/t federal charge | Federal surplus credits, offsets |
| Saskatchewan | Provincial OBPS | Regulated emitters | $95/t equivalent | Performance credits |
The gap between Alberta's headline rate ($95/tonne) and what offset credits actually trade for (often under $20) is one of the most important dynamics in Canadian carbon markets. That spread exists because the TIER system generates a large volume of credits relative to demand, which pushes market prices far below the compliance charge. Smart compliance teams exploit this gap aggressively.
Quebec's cap-and-trade market operates differently — it's a true quantity-based system linked with California's, meaning price is set by supply and demand at quarterly auctions rather than by regulation. This linkage gives Quebec's market more liquidity and a price that more closely reflects marginal abatement costs.
Worked example: Alberta oil and gas facility under TIER
Maple Creek Energy operates a natural gas processing facility in central Alberta that emits 320,000 tonnes CO2e per year. Here's how their OBPS compliance calculation works:
Step 1: Determine the benchmark. Alberta's TIER sets the emission intensity benchmark for gas processing at a facility-specific level based on historical performance, tightened annually. Maple Creek's benchmark works out to 0.038 tonnes CO2e per unit of output. With annual output of 7.2 million units, their allocated emissions are: 7,200,000 × 0.038 = 273,600 tonnes CO2e.
Step 2: Calculate the compliance gap. Actual emissions (320,000 tonnes) minus allocated emissions (273,600 tonnes) = 46,400 tonnes over the benchmark.
Step 3: Evaluate compliance options. Maple Creek can cover that 46,400-tonne gap through several routes:
- Pay the excess emissions charge: 46,400 × $95 = $4.41 million
- Purchase Alberta offset credits at market price: 46,400 × ~$18 = $835,200
- Purchase emission performance credits from other TIER facilities: Negotiated bilaterally, typically $15–$30/tonne
The cost difference is stark. Paying the headline charge costs $4.41 million. Buying offset credits at market rates costs under $900,000. In practice, Maple Creek purchases a mix of offset credits and performance credits, bringing their total compliance cost to roughly $1.1 million — about 75% below the headline rate.
Step 4: Invest in reductions. Maple Creek directs the savings into a waste-heat recovery project projected to cut facility emissions by 28,000 tonnes annually. At current credit prices, that project pays back within three years while permanently lowering their compliance exposure. Run Energy calculator to model similar facility-level energy improvements.
Headline price vs. market reality
This disconnect between the posted carbon price and what companies actually pay is one of the most misunderstood aspects of Canada's carbon market. Media coverage typically cites the federal charge ($95/tonne in 2025) as "the carbon price," but that's the ceiling, not the floor.
Actual costs depend on which province you're in, what credits are available, and how your facility performs against benchmarks. Alberta's oversupplied credit market keeps effective costs low for many emitters. Quebec's auction-driven system produces prices in the $45–55 range. BC's carbon tax applies more broadly but rebates flow back to residents and businesses.
For companies doing cross-provincial planning, this variation means your carbon cost per tonne could range from $15 to $95+ depending on where your facilities sit. Use Business carbon footprint calculator to model your exposure by location.
Key takeaway: Headline carbon prices and actual market credit prices are very different numbers: Alberta offset credits trade under $20 while the federal benchmark sits at $95, and that gap shapes compliance strategy.
The 2026 benchmark review and what's next
The federal government has flagged a comprehensive review of the OBPS benchmark stringency for 2026. Several things could change:
Tighter benchmarks. Sector-specific emission intensity limits could be lowered, meaning facilities need to be more efficient to avoid compliance costs. This would reduce the supply of surplus credits and push market prices closer to the headline rate.
Expanded coverage. The review may bring additional sectors or smaller emitters under the system. Current coverage starts at 50,000 tonnes, but some provinces have already lowered their thresholds.
Credit market reforms. The large gap between headline prices and credit market prices has drawn criticism. Reforms could include credit banking limits, vintage restrictions, or minimum pricing floors.
Consumer pricing clarity. With the fuel charge gone, the government may introduce new mechanisms to maintain consumer-facing price signals — or it may let industrial pricing drive emissions reductions indirectly through higher product costs.
Provincial elections and federal policy shifts add uncertainty. Quebec's cap-and-trade linkage with California has proven durable across political cycles, but Alberta's TIER system and BC's carbon tax both face periodic political pressure.
How to navigate Canada's carbon market
Whether you're a TIER-covered oil sands operator or a mid-sized manufacturer wondering if OBPS applies to you, the approach follows the same logic.
1. Quantify your emissions. Use Business carbon footprint calculator for corporate-wide footprints or Energy calculator for facility-level analysis. You need accurate scope 1 and 2 numbers before anything else makes sense.
2. Map your regulatory geography. Determine whether your facility falls under provincial or federal OBPS coverage. Provincial environment ministry websites publish lists of covered facilities and applicable benchmarks.
3. Model your compliance cost. Don't assume the headline price is your actual cost. Model the available credit types, current market prices, and your facility's position relative to the benchmark. The real number could be significantly lower.
4. Reduce before you buy. Every tonne cut through efficiency improvements or fuel switching is a tonne you don't need credits for. Internal abatement often costs less than credit purchases — and unlike credits, the savings compound year over year.
5. Build a multi-year strategy. With prices escalating to $170/tonne by 2030 and a benchmark review looming, short-term credit buying isn't a strategy. Invest in structural emission reductions that lower your baseline over the coming decade.
Check the carbon price tracker for current Canadian credit prices and explore verified offset projects if you need offsets after maximizing direct reductions. Canada's carbon market is complex and regionally fragmented, but the direction is clear: industrial carbon costs are going up, and early movers pay less than laggards.