September, 2026

The AER has finalized the Directive 051 changes that were circulated for feedback earlier this year. The revised directive now formally classifies high-water-content hydraulic fracturing flowback as a Class II fluid and establishes requirements for its deepwell disposal.

Other updates include clearer criteria for Class 1a and Class 1b disposal wells, recognition of additional fluids that may qualify for Class II disposal, a new requirement related to minimizing cellar space, and confirmation that disposal fluids identified on the Well Summary form must originate from an Alberta source.

A reminder that the packer is expected to be within 15 meters (TVD) above of the top of injection perforations unless technically justified. While this new Directive does not explicitly indicate a cellar space requirement, it should be noted that the length of open casing below the bottom perforations is typically also no more than15 meters (TVD) unless technically justified (for example, see Application Checklist for CO2 EOR Storage) . 

Bulletin 2026-31 | Alberta Energy Regulator

The AER has made several practical updates to Directive 020: Well Abandonment.

One useful change: AER approval is no longer required to install a wellhead when re-entering an abandoned well to assess or prepare to repair a leak. Surface and mineral rights requirements still apply.

The update also:

• Clarifies that abandonment notification applies to all abandonment types, including zonal abandonment, cut-and-cap, re-entry and reabandonment.
• Adds new qualified pools and a routine commingled abandonment region in east-central Alberta.
• Allows surface equipment on multiwell pads to remain until all wellbores on the pad have been abandoned.

Bulletin 2026-30 | Alberta Energy Regulator

The AER has set the 2027 industry closure quota at $750 million.

For licensees, the important date is September 17, 2026. The AER will use inactive liability information as of that date to calculate each company's share of the industry quota, so now is a good time to make sure licence statuses and inventory are accurate.

The AER has also extended the ability to use banked closure spending through 2028.

Bulletin 2026-33 | Alberta Energy Regulator

Alberta has resumed issuing certain Crown subsurface agreements within caribou ranges as of September 2, 2026 — but new tenure comes with an important condition.

New agreements generally cannot create new or expand existing surface disturbance within the affected caribou ranges. Development is expected to rely on existing infrastructure, previously disturbed areas or technologies that avoid additional habitat disturbance.

The change applies to certain petroleum and natural gas, oil sands, brine-hosted mineral, geothermal and subsurface storage rights. Existing tenure and commitments made before September 2 are not affected, and the interim condition does not apply within the Upper Smoky Sub-Regional Plan area.

Information Letter 2026-30 | Alberta Energy and Minerals

Effective January 1, 2027, wells still operating under Alberta's older Alberta Royalty Framework (ARF) will transition to the Modernized Royalty Framework (MRF).

Transitioning wells will not receive a C* simply because they are moving into the MRF. Instead, production after January 1 will be calculated using the Post-C royalty formula*. Production from before 2027 will continue to be recalculated under the former ARF rules where required.

Future qualifying re-entry work may still generate an incremental C* under the MRF.

Information Bulletin 2026-02 | Alberta Energy and Minerals