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The cyclic steam stimulation (CSS) process developed for the California heavy oil fields was able to produce oil from some portions of the Alberta oil sands, such as the Cold Lake oil sands, but did not work as well to produce bitumen from heavier and deeper deposits in the Athabasca oil sands and Peace River oil sands, where the majority of ...
The image below is a schematic flow diagram of a typical petroleum refinery that depicts the various refining processes and the flow of intermediate product streams that occurs between the inlet crude oil feedstock and the final end-products. The diagram depicts only one of the literally hundreds of different oil refinery configurations.
Bitumen froth treatment is a process used in the Athabasca oil sands (AOS) bitumen recovery operations to remove fine inorganics—water and mineral particles—from bitumen froth, by diluting the bitumen with a light hydrocarbon solvent—either naphthenic or paraffinic—to reduce the viscosity of the froth and to remove contaminants that ...
A process flow diagram (PFD) is a diagram commonly used in chemical and process engineering to indicate the general flow of plant processes and equipment. The PFD displays the relationship between major equipment of a plant facility and does not show minor details such as piping details and designations.
These advantages also apply to its oil sands applications, including increased oil yield, a simplified process flow, reduction of bitumen losses to tailings, elimination of the need for tailing ponds, improvement in energy efficiency compared with the hot water extraction process, and elimination of requirements for chemical and other additives ...
The process has also to be applied to heavy petroleum extracted from oil sands deposits because sulfur accumulates in the heaviest fractions of hydrocarbons. Owing to the high sulfur content of the Athabasca Oil Sands, stockpiles of elemental sulfur from this process now exist throughout Alberta, Canada. [13]
There are three types of cokers used in oil refineries: delayed coker, fluid coker and flexicoker. [2] [3] The one that is by far the most commonly used is the delayed coker. The schematic flow diagram below depicts a typical delayed coker: A typical schematic flow diagram of a delayed coking unit
Finally, the hot oil is pumped out of the well for a period of weeks or months. Once the production rate falls off, the well is put through another cycle of injection, soak and production. This process is repeated until the cost of injecting steam becomes higher than the money made from producing oil. [3]