This information was last reviewed on June 27, 2016.
The information is believed to be correct; however, please contact the company directly to confirm details.
Active Projects Announced or Under Construction
Strathcona County adjacent to Shell's Scotford facility
Facility will produce over 150 million standard cubic feet per day of hydrogen and will be connected to Air Products Canada’s existing Heartland Hydrogen Pipeline system which supplies refiners, upgraders, chemical processors and other industries in the Alberta's Industrial Heartland region
Announced project plans October 2013; site preparation and construction has begun; the facility is scheduled to be operational in 2016
Capture sites: Agrium Fertilizer Plant and North West Sturgeon Refinery, both located in Sturgeon County. Enhanced Oil Recovery site: Clive, Alberta
Enhance Energy is building the Alberta Carbon Trunk Line (ACTL). The ACTL is a 240 kilometre pipeline that will collect CO2 from industrial emitters in and around Alberta’s Industrial Heartland and transport it to aging reservoirs throughout central and southern Alberta for secure storage in enhanced oil recovery (EOR) projects. At full capacity the ACTL route will provide access to reservoirs capable of producing an additional one billion barrels of high quality light crude oil. These reservoirs will safely and securely store 14.6 million tonnes of CO2 per year as the oil is produced. At full capacity this will be equivalent to removing 2.6 million cars from Alberta’s roads. The ACTL will be the largest carbon capture and storage (CCS) project in the world. The ACTL will lay the groundwork for a cost effective industry-wide solution to the management of CO2 emissions from Alberta’s upgrading, refining, power generation and petrochemical operations. The ACTL will form the backbone of a growing CO2 gathering and transportation infrastructure which encourages and enables wide scale CCS implementation.
Total project costs close to $1 billion
Pipeline regulatory approval received in 2011; engineering and work on capture facilities at Agrium currently underway; work on facilities at North West Redwater Partnership's Sturgeon Refinery will occur in conjunction with refinery construction
ATCO Energy Solutions Ltd., in partnership with Petrogas Energy Corp., is developing four salt caverns, with the capacity to store approximately 400,000 cubic metres of propane, butane and ethylene to provide the Natural Gas Liquids (NGL) market in western Canada with a new alternative for hydrocarbon storage. The facility will be located at ATCO's Heartland Energy Centre near Fort Saskatchewan. All four caverns are fully-contracted and secured under long-term agreements.
Commercial operation for two of the salt caverns is targeted for the third quarter of 2016, with two additional salt caverns anticipated to be completed by the second quarter of 2017
An 800 megawatt (MW) natural gas-fired power generation station; the station will use natural gas-fired combined cycle technology that will produce enough electricity for approximately 400,000 homes in Alberta
Final investment decision postponed; continuing to engage with stakeholders, potential partners and key suppliers to keep all aprised until final investment decision is made
Strathcona County, three kilometres northeast of Fort Saskatchewan
ATCO Power has been selected by Williams Energy Canada to build and operate a natural gas fired cogeneration plant to meet the high pressure steam and electricity needs of Williams Energy Canada’s proposed propane dehydrogenation (“PDH”) facility
ATCO’s Final Investment Decision for the proposed 90 MW cogeneration plant is subject to Williams Energy Canada’s Final Investment Decision for the PDH facility
Pipeline is planned to start at Enbridge's existing Stonefell site and terminate at the existing Suncor East Tank Farm, near Fort McMurray
Enbridge is proposing to construct and operate a new 24" diameter pipeline system approximately 447 km in length for diluent transport. Diluent is a product term that describes various light liquid hydrocarbons, such as condensate or sythetic crude, used to dilute heavy oil to make it lighter and easier to transport or to assist in its production. The project also includes a new pump station at the existing Stonefell site.
Enbridge filed an application with the Alberta Energy Regulator and other regulatory authorities in the spring of 2014. On August 4, 2015, the Norlite Pipeline Project received approval from the AER. Construction for the project began in the summer of 2015, and will be complete and in-service by the spring of 2017.
Pipeline from Bruderheim, AB to Kitimat, BC
Proposed Enbridge Northern Gateway Pipelines project includes two adjacent 1,177 km pipelines between Bruderheim, Alberta and a deepwater terminal and tank farm in Kitimat, BC; the oil pipeline will carry 525,000 barrels of oil per day from Bruderheim to Kitimat and the second pipeline will carry 193,000 barrels of condensate per day from Kitimat to Bruderheim/
Regulatory application submitted in 2010; Government of Canada announced in June 2014 their decision to approve project subject to 209 conditions; construction pending additional approvals; target completion is late 2018
Expanding the NGL fractionation and storage facility to double the facility's existing C3+ fractionation capacity from 30,000 barrels per day to 65,000 barrels per day
Operational in 2016
The Deerland Peaking Station will be a natural-gas-fired power generation facility that produces 190 MW
Project has received all required regulatory approvals for construction; construction start date to be determined
150,000 barrel/day bitumen upgrader and diesel refinery (over 3 phases); the facility will capture 1.2 million tonnes of CO2 per year per phase, which will be sold for use in enhanced oil recovery before being sequestered
$8.5 billion for phase 1 (50,000 barrels per day)
Currently 3,800 people working at the site; project workforce to peak at 3,000-5,000 people during 2016; significant on-site construction activity is underway; phase 1 of the project expected to be operational in September 2017
Pembina's RFS II project includes expansion of the Redwater Fractionator and Storage (RFS) facility involving twinning Pembina's existing 73,000 barrel per day ethane-plus fractionator in Redwater; Pembina also announced they are proceeding with RFSIII which is a 55,000 bpd propane-plus fractionator
$415M for RFSII; $460M for RFSIII and associated pipeline
Pembina expects RFSII to be in-service late in the fourth quarter of 2015; subject to regulatory and environmental approval, RFSIII is expected to be in service in the third quarter of 2017
The gas-to-liquids facility would convert natural gas into high-quality transportation fuels and petrochemical feedstocks
Project feasibility study completed in 2012; Environmental Impact Assessment (EIA) submitted to Alberta government in May 2013; purchased 526 hectare project site in Strathcona County from Total E&P Canada in September 2013
Two parallel pipelines, approximately 460 km in length, from approximately 30 km northwest of Fort McMurray to the Edmonton area; associated Pipeline Installations will include: pump stations and tank facilities.
The project will consist of a dual pipeline system to transport crude oil and diluent between northern Alberta and the Heartland region; project includes the following components: crude oil pipeline designed and constructed to move blended bitumen from northwest of Fort McMurray to the Edmonton market, a diluent pipeline designed and constructed to move diluent from the Edmonton market to northwest of Fort McMurray, and associated facilities along the pipeline system, including pump stations and tank farms.
On October 9, 2014, the Alberta Energy Regulator approved the majority of the applications to construct and operate the Grand Rapids Pipeline Project. Grand Rapids GP Ltd began right-of-way clearing activities in the fall of 2014.
The Heartland Pipeline is a proposed crude oil pipeline from Alberta's Industrial Heartland area to the Hardisty, Alberta hub.
The project will consist of a 200 km long 36" pipeline designed to transport up to 900,000 barrels of crude oil a day; pump stations are proposed at two sites along the route
Approximately $600 million
The regulatory application was approved by the Alberta Energy Regulator in May 2015; construction will commence when appropriate given market conditions and customers' needs; communications with stakeholders and Aboriginal communities remains ongoing
The TC Terminals project is a tank terminal facility under construction in Alberta's Industrial Heartland. It will include six crude oil storage tanks with a total storage capacity of up to 1.9 million barrels, and will provide crude oil batch accumulation and terminal services.
Approximately $300 million
Received regulatory approval from the Alberta Energy Regulator in February 2014; construction began in summer 2014 with site clearing and grading; construction expected to be scheduled through to 2016.
The propane dehydrogenation (PDH) facility is designed to convert propane into higher value products and will be the first and only of its kind in Canada; will have an initial capacity of approximately 1.1 billion pounds of polymer grade propylene and 1.0 billion pounds of polypropylene
$2.5 billion combined for PDH, PP and cogen facility
Williams announced construction sanction decision of PDH facility in March 2013, pending necessary permits and approvals from regulatory authorities; facility expected to be in service in the second half of 2018
Deferred or Withdrawn Projects
BA Energy (Value Creation)
260,000 barrel/day diluted bitumen upgrader
Construction suspended in 2008; commercial and engineering work continues with the view to recommence the project
Fort Hills Energy Ltd Partnership
350,000 barrel/day bitumen upgrader
A joint venture between Suncor, Total and Teck Cominco; merger between Suncor and Petro-Canada completed in August 2009; project has received all regulatory approvals from ERCB and Alberta Environment; future construction is dependent on review currently underway at Suncor regarding the timing of their bitumen extraction and upgrading assets; the sale of UTS's 20% share of the Fort Hills project to Total E&P Canada has been completed.
Sulphur forming and handling facility
$50 - $60 million
King Tech Maple Resources
Spent catalyst recovery
StatOil Canada Ltd
240,000 barrel/day bitumen upgrader
Company withdrew regulatory application in 2008
Sulphur forming and shipping facility
Regulatory approval received in August 2009; construction will depend on timing and construction of upgraders in the Heartland area
Total E&P Canada
295,000 barrel/day bitumen upgrader
$7 - 9 billion
Project deferred; joint venture announced in December 2010 with Suncor to proceed with projects in the Fort McMurray area instead; received ERCB approval in September 2010