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🇨🇦 Alberta · PGIQ Tier 2 Strong
As of June 2026 · powergridiq.com/rating/alberta
PGIQ Rating v2 (reliability-adjusted) · as of June 2026
2

🇨🇦 Alberta

Strong, with known trade-offs, and the path is improving Reliability flags found
Tier 2 Strong · Composite 59/100, #19 of 79 markets (fundamentals 66 minus a reliability dock) · Outlook Positive · Med-High confidence · how we score

Canada's most open market: an energy-only, connect-friendly grid drawing a wave of AI data-centre announcements, with cheap gas for self-supply. What holds it back is higher power cost, a gas-heavy grid, and an interim AESO cap on large-load connections.

See live grid data →
One market,
four reads
BuildTier 2Siting ratingSellGrade COfftakePlanRisingLoad pressureMonitorSoundGrid strength
The same market, four decisions. Open any lens to see this market ranked against the rest.
Time to energize · file to power
~72 mo
File a large load today, powered ~2032. Typical range 50 to 94 months, modelled.
Application & queue entry 12mo · System study & connection offer 12mo · Transmission build 36mo · Construction & energization 12mo
End-to-end wait for a large new load, from an unstated start to an unstated end. Earlier milestones (initial, phased, temporary or conditional energization) are reported separately. A typical case, not a firm quote. · Source: AESO large-load connection process · Compare markets →
The same market, read four ways

Alberta is a limited market to sell power into

Grade C (Limited)
Offtake score 38/100
Demand 44, build feasibility 22, combined into the score. For a seller: where buyers already pay, how tight supply is, and how feasible new build is here.
Price to beat
A 100 MW load on our standard case pays about $80/MWh delivered here. A competitive supply offer works against that level.
Connection
Connection difficulty Severe, typical wait 5-8 years (queue capped).
For new supply
Abundant gas and a pro-build posture favor new generation; the binding constraint is the interim AESO large-load cap, not supply build.
Regulatory momentum
Mixed, improving. The interim AESO large-load connection cap is fully subscribed, but a durable Phase 2 framework is expected as the province writes its data-centre rules.
Beyond the grid
Indigenous consultation and water are live legal risks: Sturgeon Lake Cree Nation is seeking judicial review of Alberta's Water Act licence for the proposed roughly 70 billion dollar Wonder Valley AI campus on drought-stricken Treaty 8 land, saying it received no notice or consultation.
Scheduled to change
2026: AESO durable Phase 2 large-load connection framework expected (AESO).
See it on the Offtake Grade →

Alberta: effectively full at system level, rising demand pressure

Effectively full 3/100
System-level room, not local capacity
Local capacity: not assessed. We have found no operator publication of area or substation capacity for this market, so whether the bus serving a candidate site can take the load is an open question. Absence of a finding here is not evidence that capacity exists.
Two reads for a grid planner: how much room the system as a whole looks to have (Effectively full), and how hard demand is already pushing (Rising). The first is a market-level estimate from connection ease, forward adequacy and reliability margin. It is not local deliverability. Capacity at a specific substation is not assessed for this market, and a market can look roomy while the bus you want has nothing available. Confirm local capacity with the utility before relying on it.
Demand growth
Moderate load growth in our read, the pull on your system.
Future firm supply
Future firm supply: adequacy flagged for a large new load.
Load Pipeline Reality → Where demand is hungry → Connection friction →

Grid Risk Annex BETA

Sound
Manageable with normal diligence · grid strength 56/100
A cited, dated grid-risk read on Alberta for a capital provider, the banks and private-credit lenders, infrastructure funds and insurers holding or underwriting a power or data-centre exposure here. Drop it into a credit memo and watch each factor over the life of the exposure.
Read it against your asset. For a load asset (Buy), weight connection access and energization timing. For a generation or offtake asset (Sell), weight offtake demand, curtailment (when a plant is told to stop feeding the grid) and cost realisation. For a grid or transmission asset (Move), weight load-pipeline reality and buildout risk.
Rating and track record
PGIQ Tier 2 Strong, outlook Positive, Med-High confidence. Scored on a public, dated, falsifiable record you can cite in a credit memo.
Delivery reliability
Reliability flags found in the bulk and local outage record we reviewed.
Future firm supply
Future firm supply: adequacy flagged.
Cost certainty
Recurring cost about $80/MWh (band $60 to $110) for the standard 100 MW case, basis triangulated. Excludes connection capital.
Regulatory / stroke-of-pen
Mixed, improving. The interim AESO large-load connection cap is fully subscribed, but a durable Phase 2 framework is expected as the province writes its data-centre rules.
Execution risk
Connection friction Severe, the risk the project or load actually energizes on time.
Ongoing monitor
Track this market's rating actions and the Global Power Index as a covenant-style monitor over the life of the exposure.
Monitoring plan
Covenant-style triggers to watch over the life of the exposure: a change in the PGIQ rating or outlook; a dated regulatory move (stroke-of-pen risk); a capacity-auction or cost-band shift; a forward firm-supply adequacy warning; and a rise in queue drop-out or connection friction. Track them on this market page and the Global Power Index, or as Analyst Desk alerts.
Sources: AESO large-load process · CBC · Global News
This is a directional grid-risk screen, not a credit rating, and not investment, engineering or procurement advice.
The formatted, cited Grid Risk Annex export is an Analyst Desk feature.See the Grid Exposure Monitor →

Regulatory momentum

The regulatory and permitting environment is increasingly the binding variable for a new large load.
Mixed↑ improving

Why: The interim AESO large-load connection cap is fully subscribed, but a durable Phase 2 framework is expected as the province writes its data-centre rules.

What would change the read: AESO finalising an open, durable Phase 2 large-load connection framework.

For new supply: Abundant gas and a pro-build posture favor new generation; the binding constraint is the interim AESO large-load cap, not supply build.

Beyond the grid: Indigenous consultation and water are live legal risks: Sturgeon Lake Cree Nation is seeking judicial review of Alberta's Water Act licence for the proposed roughly 70 billion dollar Wonder Valley AI campus on drought-stricken Treaty 8 land, saying it received no notice or consultation. CBC Global News

The five pillars behind the tier

A
A
C
M
C
The pillar signature: Access, Availability, Cost, Momentum, Carbon, taller is stronger. The same shape repeats across every market so peers compare at a glance.
Access30%75

Open, energy-only market; an interim AESO large-load connection cap is in place while it studies the surge.

Availability25%62

Adequate availability (gas plus growing wind), with cheap self-supply gas.

Cost25%65

Mid-range cost.

Momentum15%60

Rising momentum: a wave of AI announcements.

Carbon5%62

Carbon moderate (~260 g), gas-led but decarbonising.

Default weights, which lean toward cost and access rather than carbon: Access 30 · Availability 25 · Cost 25 · Momentum 15 · Carbon 5. Momentum reflects the data-center build already underway, not just stated intentions.
Seller view: Read these the other way: momentum is your customer pipeline, cost is your revenue ceiling, and access is how hard it is to build and sell here, not only to connect.

Reliability overlay

Reliability adjustment: the five-pillar score of 66 is reduced to 59, a deduction of 7 points, reflecting the delivery-reliability and firm-supply risks flagged below. Reliability is reported as five separate layers, never as one combined label, because they answer different questions and a strong answer on one does not cover a gap in another: what has actually failed on the bulk system, what a forward assessment expects of firm supply, how the local network performs, what your contract actually promises, and what your site is designed to ride through. Any one of them can cap the tier.

Historical bulk-system performance: Reliability flags found

Tight supply repeatedly pushed the system to the edge in 2024: AESO declared an EEA3 grid emergency on Jan 13, 2024 with a public alert warning of imminent rotating outages, and issued a second grid alert in April 2024 that led to brief rotating outages in the Edmonton area.

What this means: A large new load should expect genuine exposure to forced power cuts (curtailment), price spikes, and delays in getting connected, and should design in backup power or firm supply contracts.

event-based · Alberta Jan/Apr 2024 event report (MSA) · AESO April 2024 grid alert (Global News)

Historical utility-territory delivery performance: No reliability flags found

Forward resource adequacy (assessed): Adequacy flagged

Recent grid alerts reflect thin reserve margins during extreme cold and low imports; market and build response is underway.

What this means: A large new load faces occasional exposure here. Monitor conditions and keep a contingency plan.

event-based

Contractual service terms: not assessed

We have not compiled what firm service actually promises here: whether it is firm, non-firm or interruptible, the conditions under which you can be curtailed, the redundancy required of you, and the transfer time behind any N-1 commitment. Treat this as an open diligence item, not as an indication that service is firm.

Ask the utility for the tariff or service agreement terms before relying on firm supply.

Designed site resilience: not applicable at market level

Utility feeds, UPS, storage, on-site generation, islanding, black start and the residual energy you still expect to lose are properties of a specific site design, not of a market. This layer only exists once there is a site, and we never assert it for you.

Confidence: High. Each input is labelled as measured, modelled, or drawn from a specific event, and is framed as a risk to a prospective large new load, not as a verdict on any utility or grid operator. Forward adequacy is an assessment of what is expected, not a measurement of what has happened; it is a forecast and is labelled as one.
Seller view: Tight forward capacity (firm supply promised for future years) is scarcity that firm generation and storage get paid for; an adequacy flag is a demand signal for new supply, not only a risk to a load.

Supply relief outlook

Will the power crunch ease before your load energizes? This nets the demand racing for capacity against the new supply likely to arrive and the old supply leaving. A cross-side read, using the same data a seller sees the other way.
Balanced
Demand pressure
Moderate load growth competing for the same capacity.
Can new supply arrive
Abundant gas and a pro-build posture favor new generation; the binding constraint is the interim AESO large-load cap, not supply build.
Future firm supply
Future firm supply: adequacy flagged.

What this means: Supply and demand look broadly balanced; the outcome hinges on the drivers below.

Connection friction

How hard it is to connect a large new load here, and how long it takes. Part of the PowerGridIQ Connection Friction Feed. Labelled measured; confidence Med-High.

Friction level

Severe

Typical connection wait

5-8 years (queue capped)

Source: AESO large-load connection process

This market's friction level, wait band and full story are free here. The precise typical wait in months, and every market ranked side by side, are the Analyst Desk.

AESO's interim 1,200 MW cap is fully allocated to two projects; about 37 more wait or must bring their own power.

The AESO's interim large-load cap of 1,200 MW is fully allocated (about 970 MW to GLDC and 230 MW to Keephills), leaving roughly 37 data-centre proposals in the queue that must self-generate or wait for grid expansion, where new transmission alone can take about ten years. A durable Phase 2 framework for loads over 75 MW is still being written, so a new grid-only load faces a multi-year wait.

What builds the 72-month wait

12
12
36
12
Application & queue entry12 mo
System study & connection offer12 mo
Transmission build36 mo
Construction & energization12 mo
Typical time to energization72 months
How the typical connection wait breaks down by stage. Stages overlap in practice and vary by project; the split is our estimate anchored to the operator process, and the total is the representative time to energization. Anchored to the operator process (AESO large-load connection process).

Data-center share of demand pressure: High. Sources: AESO large-load connection process · Alberta AI data-centre power limits (CBC). The full cross-market connection dataset is available through the Connection Friction Feed.

Seller view: Connection difficulty is both your own time-to-revenue and a barrier limiting competing supply from reaching this market.

Realized cost band

What a large electricity user pays for power here on one declared case, 100 MW contracted demand, 95% load factor, HV service, per megawatt-hour. Not the wholesale price and not the sticker tariff: energy plus the grid, delivery and other charges that land on the bill. It is a range, because real contracts vary, and it is labelled by how it was built.

Recurring cost, delivered

$60 to $110 per MWh

Midpoint about $80 per MWh

How this band was built

triangulated

From 2 public fragments

What builds the $80 midpoint

$55
$22
Wholesale pool energy$55
Transmission & distribution$22
Riders & other$3
All-in delivered$80 /MWh
How the $80/MWh figure is built up, component by component, for 100 MW contracted demand, 95% load factor, HV service. The split is our estimate; the total is the midpoint of the compiled band (triangulated). Recurring cost only: customer-funded connection capital is a separate one-off and is not included. Alberta is an energy-only market, so there is no capacity charge; the non-energy cost is transmission and distribution plus riders. Anchored to published figures (Alberta electricity rates (Utilities Consumer Advocate)).

Where the cost lands

$80
Low $60Midpoint $80High $110
A band, not a single price: the cheaper end is a well-structured contract on favourable terms, the higher end a less optimised one. The midpoint is our best central read.
What is in the number: Energy-only wholesale near $55 per MWh, plus transmission and distribution charges and riders, with no capacity market. The delivered cost sits above the pool price a large load sees.

Alberta runs an energy-only market, so the pool price is only part of the story: transmission and distribution charges add materially on top, and the province is reworking cost allocation for large loads. The delivered cost is above the headline wholesale figure, though still moderate by global standards.

This market's band is free here; the ranked cross-market table with every market's precise midpoint is the Analyst Desk. See the ranked view.

Basis: triangulated from public sources, in US dollars per MWh delivered to a large high-load-factor load, excluding refundable taxes. Sources: AESO market and pool price · Alberta electricity rates (Utilities Consumer Advocate).

Seller view: This delivered price is the level a competitive supply offer must beat, and the revenue ceiling a merchant plant works against here.

Data provenance and freshness

What we hold for this market, field by field. Each tier below is assigned from the evidence actually held for that field, with provenance. A low tier means we looked and it is thin; it is not a verdict on the market.
cost: M3connection: M2reliability: M2carbon: M2regulatory: M2local capacity: not_assessed
Against a Standardized Project Case, the binding field is connection, reliability. That is what a standardized case would turn on here; a readiness result for your own project depends on your own requirements, siting and utility, which this market-level read does not know.
Read against other uses: Discovery and monitoring: M2 · Market comparison: M2 · Project Case with a carbon requirement: M2 · Conditional site diligence: insufficient.
Depth is not a rating strength, a confidence score or a feasibility conclusion. An aggregate is only ever shown for a named use case, and equals the lowest tier across that use case's required fields. Definitions v1.0. See the full coverage matrix.
How solid the data behind this rating is, on two separate axes plus recency. Source reliability is how measured the numbers are, as opposed to triangulated or modelled. Coverage is how many of the decision-relevant data dimensions (reliability, connection, and cost) are compiled for this market. The two are kept apart because they answer different questions: a market can have strong sources on the little that is covered, or broad coverage that still leans on models. Neither grades the rating itself. The rating is a cited opinion, graded separately and falsifiably by the public track record and baseline measurement plan.

Source reliability

Moderate

1 of 3 data layers measured

Coverage

Full

3 of 3 dimensions: reliability, connection, cost

Last reviewed

June 2026

per-layer vintages below

LayerMethodVintageFreshnessSource
PGIQ Rating opinionopinionJune 2026CurrentPGIQ methodology
Reliability reviewhistorical2025FreshAlberta Jan/Apr 2024 event report (MSA)
Connection frictionmeasured2025/26FreshAESO large-load connection process
Realized costtriangulated2026FreshAESO market and pool price

Freshness reflects each layer's refresh cadence: reliability annual to three-yearly, capacity-auction and queue yearly, tariffs every year or two. The full cross-market freshness dashboard is at /data-quality.

What this market can and cannot answer yet

No market-level read closes a project case on its own, and saying only that would waste the evidence we do hold. Below is what is established, what is open, and what to do next.

What is established

  • Recurring cost band $60 to $110 per MWh, midpoint $80, basis triangulated, against the 100 MW archetype
  • Historical bulk-system performance (event-based)
  • Forward resource adequacy (assessed)

What is open

  • Historical utility-territory delivery performance (would change the answer)
  • Contractual service terms (would change the answer)
  • Designed site resilience
  • local_capacity evidence

Who would actually serve you

Not compiled for this market. Identify the serving operator before relying on any figure here, because a market-level read is an average over territories.
Who runs the connection process: not yet compiled for this market. This is wayfinding rather than evidence, and its absence is a gap in our compilation, not a fact about the market.

Credible ranges today

  • Cost $60 to $110 per MWh, midpoint $80 (triangulated)

What could disqualify this market

  • Interim large-load connection limit.
  • Power cost and carbon.

Five questions for the utility or system operator

  1. What is the available capacity at the bulk supply point and substation that would serve this site, and what would a 100 MW request do to it?
  2. Is firm service available at 100 MW, and what curtailment rights would you retain over us once we are energised?
  3. What are the milestone dates from a complete application to full firm energisation, and which network upgrades would a 100 MW load trigger?
  4. What is your own territory's SAIDI and SAIFI for the industrial class, on which major-event standard, and what redundancy serves the candidate substation?
  5. What is the all-in delivered rate for 100 MW at a 95% load factor, including demand, network and rider charges, under the tariff that would actually apply?

Documents that would advance the case

  • The area or substation capacity study, and the current queue position list.
  • The applicable large-load tariff or the draft electric service agreement.
  • The interconnection or system impact study, and a specimen connection offer.
  • The utility's own reliability filing and the substation single-line diagram.
  • The current tariff sheet with all riders, and any large-load contract terms.

Outlook drivers

↑ Upgrade triggers

  • AI announcements convert from announced to operational.
  • AESO resolves the interim large-load cap with a durable framework.

↓ Downgrade triggers

  • The interim connection cap tightens.
  • Carbon profile deters RE-mandated tenants.

Scheduled to change

Dated, already-announced events that will affect a large load sited here, in date order. These are published facts with sources, not our forecasts, and they matter most when your energization date is years out.
2026
AESO durable Phase 2 large-load connection framework expected
Replaces the interim cap (now fully subscribed); shapes whether new large loads can connect at scale.
AESO

Key risks

Peer comparison

Trades like
ERCOT (open, energy-only, gas)
Ahead
on openness vs other provinces
Behind
ERCOT on cost

Evidence behind this rating

The real-world events that test our Tier 2 call for Alberta: 2 support it. Each is dated and cited, so you can check the rating against what is actually happening on the ground.

Alberta enacts its Data Centre Regulation; AESO's bring-your-own-generation process nears rollout ✓ Supports the rating
Jul 2026AccessMateriality: med

The Data Centre Regulation AR 117/2026 (9 Jun 2026) codifies BYOG, prioritizing large data centers that bring their own generation. AESO's proposed BYOG process closed feedback 13 Jul 2026, with rollout expected Aug 2026 and intakes about every nine months.

Source: Alberta Open Government ↗
Meta breaks ground on a CAD $13B, ~1 GW AI data center in Alberta, its first in Canada ✓ Supports the rating
Jul 2026MomentumMateriality: high

Meta began construction (Jul 2026) of a roughly 1 GW, CAD $13 billion AI-optimized data center in Sturgeon County, northeast of Edmonton, its first in Canada and 33rd worldwide, with the company reporting that it will match the site's electricity to clean and renewable supply. That is a procurement commitment, not a description of the physical grid mix. A build of this scale is concrete large-load momentum on the Alberta grid, and a live test of the interim connection framework.

Source: CBC News ↗
AESO interim large-load tranche fully allocated
Jun 2026AccessMateriality: med

Phase 1 closed on 12 Jun 2026 with all 1,200 MW of the interim data-centre connection limit allocated and contracted; a durable Phase 2 framework awaits Alberta's data-centre regulation.

Source: AESO ↗
AESO sets an interim large-load connection limit amid an AI surge
2025AccessMateriality: med

A temporary cap on new large-load connections while AESO designs a durable framework for a wave of data-center interest.

Source: AESO ↗
Cited, dated developments tagged to the pillar they bear on, and whether they support or challenge the current tier. A material item flags the market for analyst review and may drive a rating action.
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Rating history

Jun 2026
AffirmedInterim tranche fully subscribed with no durable Phase 2 framework yet is a near-term access constraint, but gas-rich, pro-build fundamentals hold the tier. Affirmed; outlook watch if Phase 2 slips.
Trigger: AESO Phase 1 fully allocated (12 Jun 2026)
Jul 2026
AffirmedBYOG gives large loads a defined, if conditional, connection path after the interim tranche filled. Constructive for Access but untested until the first intake. Tier holds.
Trigger: Data Centre Regulation AR 117/2026 and AESO proposed BYOG process, Jun-Jul 2026
June 2026
New ratingNew rating: Tier 2 Strong assigned.
🔒 The full time series behind Alberta, how its score, recurring cost, and interconnection queue (the line to connect to the grid) have moved month by month, is part of the Analyst Desk. The rating actions above are always free.
Every rating action is dated and explained, and the log is only ever added to, never edited. Reviews happen on a regular schedule and whenever a significant event occurs. "Affirmed" means we reviewed a development and the tier held; "Under review" means a significant item is being assessed and the rating could change.

Score history

How Alberta's reliability-adjusted score and tier have moved, month by month. Part of your Analyst Desk.

Loading history…

How does Alberta compare to the other 78 markets?

This page is our full read on Alberta alone, and it is free. To decide where a large load should actually go, you need every market side by side, ranked on recurring cost and time-to-connect, with the history and alerts when your shortlist moves. That is the Analyst Desk.

With your Analyst Desk, compare Alberta against every market side by side, ranked on recurring cost and time-to-connect, with the full history and shortlist alerts.

+ Add to your shortlist Recurring cost, ranked Connection friction, ranked Get the Analyst Desk →
Cite as: PowerGridIQ Rating, "Alberta" (Tier 2 Strong), as of June 2026. A proprietary, directional screen for siting a large electricity load; not a connection guarantee, and not investment, engineering or procurement advice. Sources and methodology at powergridiq.com/methodology. © PowerGridIQ.