Alberta Historical Royalty Data
The royalty revenue data below is the financial data as reported in the department’s corporate documents. It is reported on a fiscal year basis (April 1 to March 31).
Revenue collected summaries fiscal year 1970/71 to 2016/17.
The following commodity based data comes from the various royalty reporting systems. Those systems are calendar year based meaning they are not directly comparable to the fiscal year revenue reported in the financial statements (annual reports) and the revenue summaries above.
Data reported on this page is;
- In the calendar year data, amendments filed by industry are reflected in the year they amend.
- This royalty systems data includes only actual invoice data.
- These calendar year numbers are not reported on financial statements, they are unaudited.
Alberta Energy calendar year statistics in Excel up to December 31, 2016 for:
Prior to 2009 conventional oil production was differentiated by vintage with the following classifications Old (pools discovered prior to 1974), New (pools discovered between 1974 and 1990) and Third Tier (pools discovered after 1990). Additionally production was broken down into Heavy and Non-heavy production. In 2009 the vintages were eliminated and production is broken down into Light, Medium, Heavy and Ultra Heavy production. The New Well Royalty Rate was a royalty reduction in 2009 and up until May 2011 when it became a permanent part of the royalty formula and is considered part of the gross royalty after May 1, 2011.
On May 1, 2011, the 2009 New Well Royalty Rate royalty reduction became a permanent part of the royalty formula. As this applies to by-products the overall effective rates are less than the previous fixed rates. In 2009 the vintages were eliminated and the gas royalty rate is based on the wells production and the gas price. By-product royalties are at fixed rates. Prior to 2009 natural gas production was differentiated by vintage with the following classifications Old (pools discovered prior to 1974), New (pools discovered between 1974 and 1990). The royalty rate was also adjusted for low productivity wells (LPWA).
Oil sands production royalties are paid in one of three ways;
- Same as conventional oil (until the project is approved)
- Under the Oil Sands royalty regulations (approved projects)
- Or under the terms of the crown agreement (older grandfathered agreements with Syncrude and Suncor)
Projects under the Oil Sands Royalty Regulations have a pre-payout or post payout status. Projects are in pre-payout until their revenues exceed allowable costs. In pre-payout status a projects pays 1 to 9% of revenues as royalties. The price of West Texas Intermediate Crude (WTI) in Canadian dollars determines that percentage and the percentage is calculated monthly.
When a project’s revenue exceeds allowable costs they move to post payout status and pay the higher amount of either their percentage of net profits or a percentage of revenues. The net revenue percentage varies between 25% and 40% based on the yearly average of the WTI price in Canadian dollars. A project does not revert to its pre-payout status if it has no profit, it will pay the percentage of revenue as royalties.
- The marker price for bitumen blend is Western Canadian Select (WCS)
- Pre Payout Data
- Post Payout Data
- Non Project Data
- Percent of bitumen Upgraded
- The information provided here is subject to periodic industry amendments
- Any discrepancy in the numbers reported is due to rounding
If you have any technical questions please contact email@example.com
This is reporting was recommended by the, "Building Confidence: Improving Accountability and Transparency in Alberta’s Royalty System " (Valentine report). Royalty calculators for comparison are available in this site.