Oil sands adapt as Western Canadian condensate gets heavier

This article was published by the Canada Energy Regulator on March 4, 2020.

Hydrocarbons, like bitumen and other heavy oils, are typically too dense to flow on major export pipelines. For example, bitumen produced in the oil sands has a density of about 1 000 kg/m³, while the maximum density of crude oil allowed on pipelines such as Trans Mountain, Keystone, and the Enbridge Mainline is 940 kg/m³.

Bitumen and other heavy oils are often diluted with lighter hydrocarbons to create “diluted bitumen” with lower density.

Common “diluents” include condensate and pentanes plus⁽¹⁾ produced in Alberta or British Columbia (B.C.), condensate imported from the United States (U.S.) (via the Cochin or Southern Lights pipelines, or by rail), synthetic crude oil, and to a lesser extent, liquefied petroleum gases like butanes.

This “pool” of diluent is changing. Combined production of Alberta and B.C. condensate and pentanes plus is growing faster than condensate imports from the U.S. Because pooled Alberta and B.C. condensate and pentanes plus are denser than imported condensate, the overall pool of diluent is growing denser.

As the overall pool of diluent changes, oil sands producers must adjust how they use it. The average density of western Canadian condensate (CRW) has increased slightly over time, reaching an average of 748 kg/m³ in 2018, while the density of Southern Lights Diluent (SLD) has remained relatively consistent, and averaged 659 kg/m³ in 2018.

This difference in density was smaller several years ago in 2013.⁽²⁾ As increasing production of western Canadian condensate and pentanes plus displaces imports, more diluent may be needed per barrel of bitumen in the future.