Solar PPAs and Lease Structures for Calgary Commercial Buildings

Quick Answer: Solar PPAs and lease structures for Calgary commercial buildings are among the three main solar financing models available to commercial buyers: capex purchase (owner buys outright, captures the 30% ITC and CCA, keeps all lifetime savings), Power Purchase Agreement (third party owns the system, owner buys electricity at a fixed contracted rate, typically 70% to 85% of utility rate), and solar lease (owner pays a fixed monthly fee for use of the system). Capex purchase delivers the strongest total return; PPAs and leases convert capex to opex at a cost to lifetime economics.

The financing decision is rarely just about cost. Capex availability, ITC capture ability, accounting treatment, and exit timing all influence the right structure. This article walks through the three models honestly, including the trade-offs that vendor pitches sometimes gloss over.

At a Glance

• Capex purchase total return: Highest (full ITC, CCA, and 25-year production)

• PPA contracted rate: 70% to 85% of utility rate, with annual escalation

• PPA term: Typically 15 to 25 years

• Lease term: Typically 10 to 20 years

• ITC and CCA capture: Goes to system owner (third party under PPA/lease)

• Capital impact: Capex (purchase) vs opex (PPA/lease)

• Buy-out options: Common in PPAs and leases at year 6 to 10

Capex Purchase: The Default Model

Outright ownership captures the most value for Calgary commercial buyers in 2026. The model is straightforward:

• Owner pays full installed cost (typically financed through a bank facility or capex allocation)

• Owner claims the 30% federal Clean Technology ITC

• Owner claims CCA Class 43.2 depreciation

• Owner consumes or sells all generated electricity for 25+ years

• Owner is responsible for maintenance, insurance, inverter replacement

The total return advantage is significant. A 100 kW capex purchase nets roughly $375,000 to $500,000 in lifetime value over 25 years. The same system under a PPA returns $150,000 to $250,000 to the building owner (the third party captures the difference).

Capex purchases are dominant in Alberta as of 2026 because:

• The federal ITC closes the payback gap inside the 10-year window

• Refundable ITC means even low-tax-burden corporations capture value

• CCA Class 43.2 stacks on top for tax-paying entities

• The PPA market in Alberta is still developing and offers smaller rate discounts than other provinces

Capex purchases make sense when:

• The owner has capex budget or can finance the project

• The owner is tax-paying or otherwise able to monetize the ITC

• The building will be held for 8+ years (full payback window)

• The owner wants the lifetime production value

Power Purchase Agreement (PPA)

A PPA is a contract between the building owner (host) and a third-party solar developer (provider). The provider owns the system, installs it on the host's roof, and sells the electricity to the host at a contracted rate. Key terms:

• Contracted rate: Typically 70% to 85% of the host's current utility rate

• Annual escalation: Usually 1% to 3% per year (sometimes flat, rarely declining)

• Term: 15 to 25 years standard

• Maintenance: Provider's responsibility

• Insurance: Provider typically insures the system; host carries policy endorsement

• Buy-out option: Often available at years 6 to 10 at fair market value

• End-of-term options: Renewal, system removal at provider cost, host purchase

The host's economics:

• No capex commitment

• Immediate energy savings (contracted rate below utility rate)

• No maintenance or replacement responsibility

• ESG and tenant-facing benefits of on-site renewable energy

• No ITC or CCA capture

The PPA market in Alberta is less developed than in provinces with regulated rate structures. Most active PPAs in Calgary involve single-tenant industrial buildings where the tenant signs the agreement directly.

Solar Lease

A solar lease is structurally similar to a PPA but priced on the system rather than the electricity. The host pays a fixed monthly lease for the right to use the system; all generated electricity flows to the host without per-kWh charges from the provider.

Key terms:

• Monthly lease payment: Fixed (or modestly escalating) for the term

• Term: Typically 10 to 20 years

• Maintenance: Often provider's responsibility but varies by contract

• Buy-out: Common at end of term or at predetermined intervals

• Tax treatment: Operating lease (off balance sheet) or capital lease (on balance sheet) depending on terms and accounting standards

Leases sit between capex purchase and PPA on the economic spectrum. They typically deliver more value than a PPA to a host that consumes most of the production, but less than outright ownership.

How the ITC and CCA Flow Through Each Structure

The federal ITC and CCA Class 43.2 are tax-driven incentives that flow to the system owner.

Capex purchase: 

Host owns the system, claims the ITC (typically $78,000 on a 100 kW system) and CCA depreciation directly.

PPA: 

Third party owns the system, claims the ITC and CCA. The host benefits indirectly through the lower contracted electricity rate (the provider passes some of the value through in pricing).

Lease: 

Depends on the lease structure. Operating leases keep ownership with the provider, who captures incentives. Capital leases (where ownership effectively transfers to the lessee) can transfer ITC and CCA capture, though specific tax treatment depends on lease terms.

For tax-paying corporations with capex availability, owning the system to capture the full ITC and CCA value typically delivers significantly more value than the rate discount on a PPA.

Lease Accounting Impact (Capital vs Operating)

Solar leases interact with accounting standards (IFRS 16 in Canada). Under current standards:

• Almost all leases above minimal value appear on the balance sheet as right-of-use assets and lease liabilities

• The historical operating-vs-capital lease distinction has largely disappeared from balance sheet treatment

• The expense pattern may differ between traditional finance leases (front-loaded interest) and traditional operating leases (straight-line expense)

For Canadian commercial owners under IFRS, the off-balance-sheet appeal of operating leases that drove some historical solar lease structures has been reduced. Most commercial solar leases now appear on the balance sheet alongside conventional financing.

This shift has made capex purchases more attractive relative to leases, since the balance sheet impact is now similar.

Lender and Landlord Considerations

Commercial real estate lenders increasingly accept solar as a value-add asset. Specific considerations:

• Mortgage covenants. Some commercial mortgages restrict additional liens or third-party equipment ownership. PPA and lease contracts may require lender consent.

• Building appraisal. Solar adds value to the building appraisal in most cases, especially with ESG-driven buyers and tenants.

• Transfer obligations. PPAs and leases must transfer to a new owner on sale. The new owner inherits the contract. Lender consent to assumption is sometimes required.

Multi-tenant landlords face additional considerations around pass-through and shared benefit. Net billing credits typically flow to the meter holder (often the landlord in common-area metering or the tenant in direct metering). Lease structures often allocate solar production benefit to tenants through reduced electricity charges or CAM (common area maintenance) adjustments.

Pass-Through to Tenants in Multi-Tenant Buildings

Multi-tenant commercial buildings can structure solar benefit pass-through in several ways:

• CAM reduction. Solar production offsets common-area electricity, reducing CAM charges to tenants

• Direct tenant supply. Solar production allocated to specific tenants through sub-metering

• Sustainability credit. Tenants receive a documented sustainability credit for use in ESG reporting even without direct electricity cost reduction

The structure depends on lease language. Modern green leases increasingly include solar pass-through provisions explicitly. Older leases may need amendment to accommodate the new arrangement.

End-of-Term and Exit Considerations

What happens at the end of a PPA or lease term matters as much as the entry economics.

PPA end-of-term options:

• Contract renewal at renegotiated rate

• System purchase at fair market value (typically 10% to 25% of original cost)

• System removal at provider's cost

• Continuation under month-to-month terms

Lease end-of-term options:

• Buy-out at predetermined price

• Renewal at renegotiated lease payment

• System removal

Capex purchase exit: None required. Owner continues to operate or sells with the building.

If the host plans to sell the building before the PPA or lease term ends, the contract transfers to the new owner. New owner approval is sometimes required, and some buyers view third-party contracts as friction. Capex-owned systems are simpler in sale scenarios.

When Each Structure Wins

Solar PPAs and lease structures for Calgary commercial buildings can make more sense than an outright purchase in specific situations, depending on the owner's capital, tax position, maintenance preferences, and expected hold period.

Capex purchase wins when:

• Building will be held 8+ years

• Owner is tax-paying or able to monetize the refundable ITC

• Capex budget is available, or financing is accessible

• Owner wants lifetime production value

• Owner wants asset on balance sheet for ESG asset reporting

PPA wins when:

• Capex is constrained

• Owner is unable to monetize ITC (very rare with refundability)

• Building is single-tenant industrial with the tenant willing to sign

• Owner wants zero maintenance responsibility

• Short hold period limits payback realization

Lease wins when:

• A middle ground between capex and PPA is desired

• Tax position favours expense over depreciation

• Owner wants system flexibility without ownership

Frequently Asked Questions

Can the PPA price escalate?

Yes, most PPAs include annual escalation clauses of 1% to 3%. This means the rate discount narrows over time relative to utility rates. Some PPAs include rate caps or floors. Review the escalator carefully; aggressive escalation can erode the value proposition by years 10 to 15.

What happens at end of PPA term?

Three options typically: contract renewal at a renegotiated rate, system purchase at fair market value (often 10% to 25% of original installed cost), or system removal at the provider's expense. The contract specifies which options apply and at what notice periods.

Can I buy out the lease early?

Most leases include early buy-out provisions, often at years 6, 10, and 15. Buy-out prices are typically defined in the original contract. Early buy-out can convert a lease arrangement into capex ownership and capture remaining lifetime value, though it requires capital availability at the buy-out date.

How do I know if a PPA rate is fair?

Compare the PPA rate to your current utility blended rate, including all riders, distribution, transmission, and demand charges. The PPA should offer a meaningful discount (15% to 30% typical) in the early years. Verify the escalator and confirm the comparison includes all utility components, not just the commodity rate.

About Angel's Roofing: Angel's Roofing provides Calgary commercial solar installation throughout Calgary and surrounding areas, specializing in roofing-led project coordination and independent guidance on capex, PPA, and lease structures for property managers and building owners requiring honest financing comparison.

Ready to evaluate the right financing structure for your Calgary commercial solar project? Angel's Roofing helps Calgary property managers and building owners assess capex, PPA, and lease options against their specific tax position and building strategy, backed by 25+ years of Calgary commercial experience.

Contact us today at 403-569-2643 to discuss commercial solar financing options for your building.

Disclaimer: Roofing involves safety risks; consult licensed professionals for work beyond ground-level visual checks. Costs and specifications provided are estimates based on typical Calgary market conditions and may vary based on specific project requirements and current material pricing.