About Enbridge

Enbridge Inc. (Enbridge) operates as an energy infrastructure company in North America. Segments The company operates through five segments: Liquids Pipelines, Gas Transmission and Midstream, Gas Distribution and Storage, Renewable Power Generation, and Energy Services. Liquids Pipelines segment This segment consists of pipelines and terminals in Canada and the U.S. that transport various grades of crude oil and other liquid hydrocarbons. Mainline System The Mainline System includes the Canadian Mainline and the Lakehead System. The Canadian Mainline is a common carrier pipeline system, which transports various grades of crude oil and other liquid hydrocarbons within western Canada and from western Canada to the Canada/the U.S. border near Gretna, Manitoba and Neche, North Dakota and from the U.S./Canada border near Port Huron, Michigan and Sarnia, Ontario to eastern Canada and the northeastern U.S. The Canadian Mainline includes six adjacent pipelines with a combined operating capacity of approximately 3.1 million barrels per day (mmbpd) that connect with the Lakehead System at the Canada/the U.S. border, as well as five pipelines that deliver crude oil and refined products into eastern Canada and the northeastern U.S. The Lakehead System is the portion of the Mainline System in the U.S. It is an interstate common carrier pipeline system regulated by the Federal Energy Regulatory Commission (FERC) and is the primary transporter of crude oil and liquid petroleum from western Canada to the U.S. Tolling Framework The Competitive Toll Settlement (CTS), which governed tolls paid for products shipped on the Canadian Mainline, with the exception of Lines 8 and 9 which are tolled on a separate basis, expired on June 30, 2021. As of July 1, 2021, the Mainline System is on Interim Tolls, which will remain in effect until new tolls are approved by the Canada Energy Regulator (CER). In accordance with the terms of the CTS, Interim Tolls are equal to the CTS exit tolls on June 30, 2021 and are subject to finalization and adjustment applicable to the interim period, if any. The company is exploring, with customers and other stakeholders, alternatives that may include a modified and extended CTS, a new incentive rate-making agreement, or a cost-of-service rate-making structure. Any negotiated settlement would require CER approval before implementation. New tolling framework clarity is expected by 2023. Lakehead System Local Tolls Transportation rates are governed by the FERC for deliveries from the Canada/United States border near Neche, North Dakota, Clearbrook, Minnesota and other points to principal delivery points on the Lakehead System. The Lakehead System periodically adjusts these transportation rates as allowed under the FERC’s index methodology and tariff agreements, the main components of which are index rates and the Facilities Surcharge Mechanism. Regional Oil Sands System The Regional Oil Sands System includes five intra-Alberta long-haul pipelines; the Athabasca Pipeline, Waupisoo Pipeline, Woodland Pipeline, Wood Buffalo Extension/Athabasca Twin pipeline system and the Norlite Pipeline System (Norlite), as well as two large terminals, such as the Athabasca Terminal located north of Fort McMurray, Alberta and the Cheecham Terminal, located south of Fort McMurray, Alberta. The Regional Oil Sands System also includes various laterals and related facilities, which provide access for oil sands production from twelve producing oil sands projects. The combined capacity of the intra-Alberta long-haul pipelines is approximately 1,090 thousand barrels per day (kbpd) to Edmonton and 1,370 kbpd into Hardisty, with the Norlite Pipeline System (Norlite) providing approximately 218 kbpd of diluent capacity into the Fort McMurray region. The company has a 50% interest in the Woodland Pipeline and a 70% interest in Norlite. The Regional Oil Sands System is anchored by long-term agreements with multiple oil sands producers. Gulf Coast and the Mid-Continent Gulf Coast includes Seaway Crude Pipeline System (Seaway Pipeline), Flanagan South Pipeline (Flanagan South), Spearhead Pipeline, Gray Oak Pipeline and the Enbridge Ingleside Energy Center (EIEC), as well as the Mid-Continent System (Cushing Terminal). The company has a 50% interest in the 1,078-kilometer (670-mile) Seaway Pipeline, including the 805-kilometer (500-mile), 30-inch diameter long-haul system between Cushing, Oklahoma and Freeport, Texas, as well as the Texas City Terminal and Distribution System, which serve refineries in the Houston and Texas City areas. Total aggregate capacity on the Seaway Pipeline system is approximately 950 kbpd. Seaway Pipeline also includes 8.8 million barrels of crude oil storage tank capacity on the Texas Gulf Coast. Flanagan South is a 950-kilometer (590-mile), 36-inch diameter interstate crude oil pipeline that originates at the company’s terminal at Flanagan, Illinois, a delivery point on the Lakehead System, and terminates in Cushing, Oklahoma. Flanagan South has a capacity of approximately 600 kbpd. Spearhead Pipeline is a long-haul pipeline that delivers crude oil from Flanagan, Illinois, a delivery point on the Lakehead System, to Cushing, Oklahoma. The Spearhead pipeline has a capacity of approximately 193 kbpd. The Gray Oak pipeline is a 1,368-kilometer (850-mile) crude oil system, which runs from the Permian Basin in West Texas to the U.S. Gulf Coast. The Gray Oak pipeline has an expected average annual capacity of 900 kbpd and transports light crude oil. The company has an effective 22.8% interest in the pipeline. Initial in-service for the pipeline commenced in November 2019 with full service achieved in the second quarter of 2020. The Mid-Continent System includes storage terminals at Cushing, Oklahoma (Cushing Terminal), including over 80 individual storage tanks ranging in size from 78 to 570 thousand barrels. Total storage shell capacity of Cushing Terminal is approximately 20 million barrels. A portion of the storage facilities are used for operational purposes, while the remainder are contracted to various crude oil market participants for their term storage requirements. In October 2021, the company acquired a 100 percent operating interest in the Ingleside Energy Center (renamed the Enbridge Ingleside Energy Center (EIEC)), located near Corpus Christi, Texas. This terminal includes 15.6 million barrels of storage and 1.5 million barrels per day of export capacity. The company also acquired a 20% interest in the 670-kbpd Cactus II Pipeline, LLC (Cactus II) Pipeline, a 100% interest in the 300-kbpd Viola pipeline, and a 100% interest in the 350-thousand-barrel Taft Terminal. Other Other includes Southern Lights Pipeline, Express-Platte System, Bakken System and Feeder Pipelines and Other. Southern Lights Pipeline is a single stream 180 kbpd 16/18/20-inch diameter pipeline that ships diluent from the Manhattan Terminal near Chicago, Illinois to three western Canadian delivery facilities, located at the Edmonton and Hardisty terminals in Alberta and the Kerrobert terminal in Saskatchewan. Both the Canadian portion of Southern Lights Pipeline and the U.S. portion of Southern Lights Pipeline receive tariff revenues under long-term contracts with committed shippers. Southern Lights Pipeline capacity is 90% contracted with the remaining 10% of the capacity assigned for shippers to ship uncommitted volumes. The Express-Platte System consists of the Express pipeline and the Platte pipeline, and crude oil storage of approximately 5.6 million barrels. It is an approximate 2,736-kilometer (1,700-mile) long crude oil transportation system, which begins at Hardisty, Alberta, and terminates at Wood River, Illinois. The 310 kbpd Express pipeline carries crude oil to U.S. refining markets in the Rocky Mountains area, including Montana, Wyoming, Colorado and Utah. The 145 to 164 kbpd Platte pipeline, which interconnects with the Express pipeline at Casper, Wyoming, transports crude oil primarily from the Bakken shale and western Canada to refineries in the midwest. Express pipeline capacity is typically committed under long-term take-or-pay contracts with shippers. A portion of Express pipeline capacity and all of the Platte pipeline capacity is used by uncommitted shippers who pay only for the pipeline capacity they actually use in a given month. The Bakken System consists of the North Dakota System and the Bakken Pipeline System. The North Dakota System services the Bakken in North Dakota and includes a crude oil gathering and interstate pipeline transportation system. The gathering system provides delivery to Clearbrook, Minnesota for service on the Lakehead system or various interconnecting pipeline and rail export facilities. The interstate portion of the system has both the U.S. and Canadian components that extend from Berthold, North Dakota into Cromer, Manitoba. Tariffs on the U.S. portion of the North Dakota System are governed by the FERC. The Canadian portion is categorized as a Group 2 pipeline, and as such, its tolls are regulated by the CER on a complaint basis. Tolls on the interstate pipeline system are based on long-term take-or-pay agreements with anchor shippers. The company has an effective 27.6% interest in the Bakken Pipeline System, which connects the Bakken formation in North Dakota to markets in eastern PADD II and the U.S. Gulf Coast. The Bakken Pipeline System consists of the Dakota Access Pipeline from the Bakken area in North Dakota to Patoka, Illinois, and the Energy Transfer Crude Oil Pipeline from Patoka, Illinois to Nederland, Texas. Capacity is 750 kbpd of crude oil with the potential to be expanded through additional pumping horsepower. The Bakken Pipeline System is anchored by long-term throughput commitments from a number of producers. Feeder Pipelines and Other includes various liquids storage assets and pipeline systems in Canada and the U.S. Key assets included in Feeder Pipelines and Other are the Hardisty Contract Terminal and Hardisty Storage Caverns located near Hardisty, Alberta, a key crude oil pipeline hub in western Canada and the Southern Access Extension (SAX) pipeline, which originates in Flanagan, Illinois and delivers to Patoka, Illinois. The company has an effective 65% interest in the 300 kbpd SAX (the Southern Access Extension) pipeline of which the majority of its capacity is commercially secured under long-term take-or-pay contracts with shippers. Feeder Pipelines and Other also includes Patoka Storage, the Toledo pipeline system and the Norman Wells (NW) System. Patoka Storage includes four storage tanks with 480 thousand barrels of shell capacity located in Patoka, Illinois. The 101 kbpd Toledo pipeline system connects with the Lakehead System and delivers to Ohio and Michigan. The 45 kbpd NW System transports crude oil from Norman Wells in the Northwest Territories to Zama, Alberta and has a rate structure based on established terms with shippers. Gas Transmission and Midstream segment This segment consists of the company’s investments in natural gas pipelines and gathering and processing facilities in Canada and the U.S., including the U.S. Gas Transmission, Canadian Gas Transmission, the U.S. Midstream and other assets. The U.S. Gas Transmission The U.S. Gas Transmission includes ownership interests in Texas Eastern Transmission, L.P. (Texas Eastern); Algonquin Gas Transmission, LLC (Algonquin); Maritimes & Northeast (M&N) (the U.S. and Canada); East Tennessee Natural Gas, LLC (East Tennessee); Gulfstream Natural Gas System, L.L.C. (Gulfstream); Sabal Trail Transmission (Sabal Trail); NEXUS Gas Transmission Pipeline (NEXUS); Valley Crossing Pipeline, LLC. (Valley Crossing); Southeast Supply Header (SESH); Vector Pipeline L.P. (Vector); and certain other gas pipeline and storage assets. The U.S. Gas Transmission business primarily provides transmission and storage of natural gas through interstate pipeline systems for customers in various regions of the northeastern, southern and midwestern U.S. The Texas Eastern natural gas transmission system extends from supply and demand centers in the Gulf Coast region of Texas and Louisiana to supply and demand centers in Ohio, Pennsylvania, New Jersey and New York. Texas Eastern's onshore system has a peak day capacity of 13.09 billion cubic feet per day (bcf/d) of natural gas on approximately 13,807-kilometers (8,579-miles) of pipeline and associated compressor stations. Texas Eastern is also connected to four affiliated storage facilities that are partially or wholly-owned by other entities within the U.S. Gas Transmission business. The Algonquin natural gas transmission system connects with Texas Eastern’s facilities in New Jersey and extends through New Jersey, New York, Connecticut, Rhode Island and Massachusetts where it connects to Maritimes & Northeast (M&N) US. The system has a peak day capacity of 3.09 bcf/d of natural gas on approximately 1,820-kilometers (1,131-miles) of pipeline with associated compressor stations. M&N US has a peak day capacity of 0.83 bcf/d of natural gas on approximately 552-kilometers (343-miles) of mainline interstate natural gas transmission system, including associated compressor stations, which extends from northeastern Massachusetts to the border of Canada near Baileyville, Maine. M&N Canada has a peak day capacity 0.55 bcf/d on approximately 885-kilometers (550-miles) of interprovincial natural gas transmission mainline system that extends from Goldboro, Nova Scotia to the U.S. border near Baileyville, Maine. The company has a 78% interest in M&N US and M&N Canada. East Tennessee’s natural gas transmission system has a peak day capacity of 1.86 bcf/d of natural gas, crosses Texas Eastern’s system at two locations in Tennessee and consists of two mainline systems totaling approximately 2,456-kilometers (1,526-miles) of pipeline in Tennessee, Georgia, North Carolina and Virginia, with associated compressor stations. East Tennessee has an LNG storage facility in Tennessee and also connects to the Saltville storage facilities in Virginia. Gulfstream is an approximately 1,199-kilometer (745-mile) interstate natural gas transmission system with associated compressor stations. Gulfstream has a peak day capacity of 1.31 bcf/d of natural gas from Mississippi, Alabama, Louisiana and Texas, crossing the Gulf of Mexico to markets in central and southern Florida. The company has a 50% interest in Gulfstream. Sabal Trail Transmission (Sabal Trail) is an approximately 832-kilometer (517-mile) pipeline that provides firm natural gas transportation. Facilities include a pipeline, laterals and various compressor stations. The pipeline infrastructure is located in Alabama, Georgia and Florida, and adds approximately 1.0 bcf/d of capacity enabling the access of onshore gas supplies. The company has a 50% interest in Sabal Trail. NEXUS is an approximately 414-kilometer (257-mile) interstate natural gas transmission system with associated compressor stations. NEXUS transports natural gas from the company’s Texas Eastern system in Ohio to its Vector interstate pipeline in Michigan, with peak day capacity of 1.4 bcf/d. Through its interconnect with Vector, NEXUS provides a connection to Dawn Hub, the largest integrated underground storage facility in Canada and one of the largest in North America, located in southwestern Ontario adjacent to the Greater Toronto Area. The company has a 50% interest in NEXUS. Valley Crossing is an approximately 285-kilometer (177-mile) intrastate natural gas transmission system, with associated compressor stations. The pipeline infrastructure is located in Texas and provides market access of up to 2.6 bcf/d of design capacity to the Comisión Federal de Electricidad, Mexico’s state-owned utility. Southeast Supply Header (SESH) is an approximately 462-kilometer (287-mile) natural gas transmission system with associated compressor stations. SESH extends from the Perryville Hub in northeastern Louisiana where the shale gas production of eastern Texas, northern Louisiana and Arkansas, along with conventional production, is reached from six major interconnections. SESH extends to Alabama, interconnecting with 14 major north-south pipelines and three high-deliverability storage facilities and has a peak day capacity of 1.1 bcf/d of natural gas. The company has a 50% interest in SESH. Vector is an approximately 560-kilometer (348-mile) pipeline travelling between Joliet, Illinois in the Chicago area and Ontario. Vector can deliver 1.745 bcf/d of natural gas, of which 455 million cubic feet per day (mmcf/d) is leased to NEXUS. The company has a 60% interest in Vector. Transmission and storage services are generally provided under firm agreements where customers reserve capacity in pipelines and storage facilities. The majority of these agreements provide for fixed reservation charges that are paid monthly regardless of the actual volumes transported on the pipelines, plus a small variable component that is based on volumes transported, injected or withdrawn, which is intended to recover variable costs. Interruptible transmission and storage services are also available where customers can use capacity if it exists at the time of the request and are generally at a higher toll than long-term contracted rates. Storage operations also provide a variety of other value-added services, including natural gas parking, loaning and balancing services to meet customers’ needs. Canadian Gas Transmission Canadian Gas Transmission includes Westcoast Energy Inc.’s (Westcoast) British Columbia (BC) Pipeline, Alliance Pipeline and other minor midstream gas gathering pipelines. BC Pipeline has a peak day capacity of 3.6 bcf/d of natural gas on approximately 2,950-kilometers (1,833-miles) of transmission pipeline in BC and Alberta that includes associated mainline compressor stations. It provides cost-of-service based natural gas transmission services. Alliance Pipeline is an approximately 3,000-kilometer (1,864-mile) integrated, high-pressure natural gas transmission pipeline with approximately 860-kilometers (534-miles) of lateral pipelines and related infrastructure. It transports liquids-rich natural gas from northeast BC, northwest Alberta and the Bakken area in North Dakota to the Alliance Chicago gas exchange hub downstream of the Aux Sable (Aux Sable Liquid Products LP and Aux Sable Midstream LLC, and a 50% interest in Aux Sable Canada LP (collectively, Aux Sable)) natural gas liquid (NGL) extraction and fractionation plant at Channahon, Illinois. The system has a peak day capacity of 1.8 bcf/d of natural gas. The company has a 50% interest in Alliance Pipeline. The majority of transportation services provided by Canadian Gas Transmission are under firm agreements, which provide for fixed reservation charges that are paid monthly regardless of actual volumes transported on the pipeline, plus a small variable component that is based on volumes transported to recover variable costs. Canadian Gas Transmission also provides interruptible transmission services where customers can use capacity if it is available at the time of request. The U.S. Midstream The U.S. Midstream includes a 42.7% interest in each of Aux Sable Liquid Products LP and Aux Sable Midstream LLC, and a 50% interest in Aux Sable Canada LP (collectively, Aux Sable). Aux Sable Liquid Products LP owns and operates an NGL extraction and fractionation plant at Channahon, Illinois, outside Chicago, near the terminus of Alliance Pipeline. Aux Sable also owns facilities connected to Alliance Pipeline that facilitate the delivery of liquids-rich natural gas for processing at the Aux Sable plant. These facilities include the Palermo Conditioning Plant and the Prairie Rose Pipeline in the Bakken area of North Dakota, owned and operated by Aux Sable Midstream US; and Aux Sable Canada’s interests in the Montney area of BC, including the Septimus Pipeline. Aux Sable Canada also owns a facility, which processes refinery/upgrader offgas in Fort Saskatchewan, Alberta. The U.S. Midstream also includes a 50% investment in DCP Midstream, LLC (DCP Midstream), which indirectly owns approximately 57% of DCP Midstream, LP, including limited partner and general partner interests. DCP Midstream, LP is a master limited partnership, with a diversified portfolio of assets, which engages in the business of gathering, compressing, treating, processing, transporting, storing and selling natural gas; producing, fractionating, transporting, storing and selling NGLs; and recovering and selling condensate. DCP Midstream, LP owns and operates more than 36 plants and approximately 90,123-kilometers (56,000-miles) of natural gas and natural gas liquids pipelines, with operations in nine states across major producing regions. Other Other consists primarily of the company’s offshore assets. Enbridge Offshore Pipelines includes 11 natural gas gathering and the Federal Energy Regulatory Commission (FERC) regulated transmission pipelines and four oil pipelines. These pipelines are located in four major corridors in the Gulf of Mexico, extending to deepwater developments, and include approximately 2,100-kilometers (1,300-miles) of underwater pipe and onshore facilities with total capacity of approximately 6.5 bcf/d. Gas Distribution and Storage segment This segment consists of the company’s natural gas utility operations, the core of which is Enbridge Gas Inc. (Enbridge Gas), which serves residential, commercial and industrial customers throughout Ontario. This segment also includes natural gas distribution activities in Québec and previously included an investment in Noverco Inc. (Noverco), which was sold in December 2021. Enbridge Gas Enbridge Gas is a rate-regulated natural gas distribution utility with storage and transmission services. Enbridge Gas serves approximately 75% of Ontario residents via approximately 3.8 million residential, commercial and industrial meter connections. There are three principal interrelated aspects of the natural gas distribution business in which Enbridge Gas is directly involved, including distribution, transportation and storage. In 2021, Enbridge Gas implemented a voluntary renewable natural gas (RNG) pilot program, whereby customers can voluntarily contribute towards the incremental cost of low carbon RNG to displace regular natural gas, and a pilot project which allows regular natural gas to be blended with H2, in an isolated portion of the existing distribution system, in an effort to gain insight into the use of H2 as a method for decarbonizing natural gas for the purpose of reducing greenhouse gas (GHG) emissions. Distribution Enbridge Gas’ principal source of revenue arises from distribution of natural gas to customers. The services provided to residential, small commercial and industrial heating customers are primarily on a general service basis, without a specific fixed term or fixed price contract. The services provided to larger commercial and industrial customers are usually on an annual contract basis under firm or interruptible service contracts. Under a firm contract, Enbridge Gas is obligated to deliver natural gas to the customer up to a maximum daily volume. The service provided under an interruptible contract is similar to that of a firm contract, except that it allows for service interruption at Enbridge Gas’ option primarily to meet seasonal or peak demands. The Ontario Energy Board (OEB) approves rates for both contract and general services. The distribution system consists of approximately 147,000-kilometers (91,342-miles) of pipelines that carry natural gas from the point of local supply to customers. Customers have a choice with respect to natural gas supply. Customers may purchase and deliver their own natural gas to points upstream of the distribution system or directly into Enbridge Gas’ distribution system, or, alternatively, they may choose a system supply option, whereby customers purchase natural gas from Enbridge Gas’ supply portfolio. To acquire the necessary volume of natural gas to serve its customers, Enbridge Gas maintains a diversified natural gas supply portfolio, acquiring supplies on a delivered basis in Ontario, as well as acquiring supply from multiple supply basins across North America. Transportation Enbridge Gas contracts for firm transportation service, primarily with TransCanada Pipelines Limited (TransCanada), Vector and NEXUS, to meet its annual natural gas supply requirements. The transportation service contracts are not directly linked with any particular source of natural gas supply. Separating transportation contracts from natural gas supply allows Enbridge Gas flexibility in obtaining its own natural gas supply and accommodating the requests of its direct purchase customers for assignment of TransCanada capacity. Enbridge Gas forecasts the natural gas supply needs of its customers, including the associated transportation and storage requirements. In addition to contracting for transportation service, Enbridge Gas offers firm and interruptible transportation services on its own Dawn-Parkway pipeline system. Enbridge Gas’ transmission system consists of approximately 5,500-kilometers (3,418-miles) of high-pressure pipeline and five mainline compressor stations and has an effective peak daily demand capacity of 7.6 bcf/d. Enbridge Gas’ transmission system also links a network of underground storage pools at the Tecumseh Gas Storage facility and Dawn Hub (collectively, Dawn) to major Canadian and the U.S. markets, and forms an important link in moving natural gas from western Canada and the U.S. supply basins to central Canadian and northeastern U.S. markets. Enbridge Gas delivered 1,943 bcf of gas through its distribution and transmission system in 2021. A substantial amount of Enbridge Gas’ transportation revenue is generated by fixed annual demand charges, with the average length of a long-term contract being approximately 15 years and the longest remaining contract term being 19 years. Storage Enbridge Gas’ business is highly seasonal as daily market demand for natural gas fluctuates with changes in weather, with peak consumption occurring in the winter months. The utilization of storage facilities permits Enbridge Gas to take delivery of natural gas on favorable terms during off-peak summer periods for subsequent use during the winter heating season. Enbridge Gas’ storage facility at Dawn is located in southwestern Ontario, and has a total working capacity of approximately 281 bcf in 34 underground facilities located in depleted gas fields. Dawn is an integrated underground storage facility in Canada and one of the largest in North America. Approximately 180 bcf of the total working capacity is available to Enbridge Gas for utility operations. Enbridge Gas also has storage contracts with third parties for 21 bcf of storage capacity. Dawn offers customers an important link in the movement of natural gas from western Canadian and the U.S. supply basins to markets in central Canada and the northeast U.S. Dawn's configuration provides flexibility for injections, withdrawals and cycling. Customers can purchase both firm and interruptible storage services at Dawn. Dawn offers customers a range of market choices and options with access to upstream and downstream markets. During 2021, Dawn provided services, such as storage, balancing, gas loans, transport, exchange and peaking services to over 200 counterparties. A substantial amount of Enbridge Gas’ storage revenue is generated by fixed annual demand charges, with the average length of a long-term contract being approximately four years and the longest remaining contract term being 15 years. Noverco Noverco Inc. (Noverco) is a holding company that wholly-owns Énergir, LP (Énergir), a natural gas distribution company operating in Québec, with interests in subsidiary companies operating gas transmission, gas distribution and power distribution businesses in Québec and Vermont. Énergir serves approximately 525,000 residential and industrial customers and is regulated by the Québec Régie de l’énergie and the Vermont Public Utility Commission. Noverco also holds an investment in the company’s common shares. The company owned an equity interest in Noverco through ownership of 38.9% of its common shares and an investment in its preferred shares. In December 2021, the company sold its 38.9% non-operating minority ownership interest in Noverco to Trencap L.P. Gazifère The company wholly owns Gazifère Inc. (Gazifère), a natural gas distribution company that serves approximately 44,000 customers in western Québec, a market not served by Énergir, LP (Énergir). Gazifère is regulated by the Québec Régie de l’énergie. Renewable Power Generation segment Renewable Power Generation consists primarily of investments in wind and solar assets, as well as geothermal, waste heat recovery, and transmission assets. In North America, assets are primarily located in the provinces of Alberta, Saskatchewan, Ontario, and Québec and in the states of Colorado, Texas, Indiana and West Virginia. The company is also developing several solar self-power projects along its oil and gas rights-of-way in North America. In Europe, the company holds equity interests in operating offshore wind facilities in the coastal waters of the United Kingdom and Germany, as well as interests in several offshore wind projects under construction and active development in France. Further, it is pursuing new European offshore wind development opportunities through Maple Power Ltd., a joint venture in which the company holds a 50% interest. Combined Renewable Power Generation investments represent approximately 2,178 megawatts (MW) of net generation capacity. Of this amount, approximately 1,392 MW is generated by North American wind facilities; 255 MW is generated by European offshore wind facilities; 309 MW will be generated by the Saint-Nazaire, Fécamp and Calvados Offshore Wind projects, all of which are under construction; 6 MW will be generated by the Provence Grand Large Floating Offshore Wind project, which secured funding in 2021 and continues to prepare onshore construction; and 93 MW is generated by North American solar facilities in operation, with an additional 97 MW in projects in early construction and under-construction. The majority of the power produced from these facilities is sold under long-term Power Purchase Agreements (PPAs). Renewable Power Generation also includes the company’s 25% interest in the East-West Tie, a 450-MW transmission line in northwestern Ontario, which is under construction and is expected to reach commercial operation in the first half of 2022. Joint Ventures/Equity Investments The investments in the Canadian wind and solar assets (excluding self-power) and two of the U.S. renewable assets are held within a joint venture in which the company maintains a 51% interest and which it manages and operates. The company also owns interests in European offshore wind facilities through various joint ventures, including a 24.9% interest in Rampion Offshore Wind Limited (Rampion Offshore Wind), located in the United Kingdom; a 25.4% interest in Hohe See Offshore and its subsequent expansion, located in Germany; a 25.5% interest in the Saint-Nazaire Offshore Wind project, under construction in France; a 25% interest in the Provence Grande Large Floating Offshore Wind project, in pre-construction in France; a 17.9% interest in the Fécamp Offshore Wind project, under construction in France; and a 21.7% interest in the Calvados Offshore Wind project, in pre-construction in France. The ownership interest percentages in the Saint-Nazaire, Fécamp, and Calvados Offshore Wind projects reflect the sale of 49% of an entity that holds its 50% interest in Éolien Maritime France SAS (EMF) to the Canada Pension Plan Investment Board (CPP Investments), which closed in the first half of 2021. Energy Services segment This segment engages in Canada and the U.S. provide physical commodity marketing and logistical services to North American refiners, producers, and other customers. This segment primarily focuses on servicing customers across the value chain and capturing value from quality, time, and location price differentials when opportunities arise. To execute these strategies, Energy Services transports and stores on both Enbridge-owned and third party assets using a combination of contracted long-term and short-term pipeline, storage, railcar, and truck capacity agreements. Regulation In the U.S., the company’s interstate pipeline operations are subject to pipeline safety laws and regulations administered by the Pipeline and Hazardous Materials Safety Administration (PHMSA), an agency within the United States Department of Transportation. The company’s ability to establish transportation and storage rates on its U.S. interstate natural gas facilities are subject to regulation by the FERC, whose rulings and policies could have an adverse impact on the ability of such pipeline and storage assets to recover their respective full cost of operating, including a reasonable rate of return. In Canada, the company’s pipeline operations are subject to pipeline safety regulations administered by the CER or provincial regulators. The company’s Mainline System and other liquids pipelines and gas transmission facilities are subject to the actions of various regulators, including the CER and the FERC, with respect to the tariffs and tolls of those pipelines. Its gas distribution and storage utility operations are regulated by the Ontario Energy Board (OEB) and the Québec Régie de l’énergie, among others. The company’s Renewable Power Generation assets in France and Germany each have federal policies in place and are subject to directives and regulations established and enforced by the European Union (EU). These include the Renewable Energy Directive (RED II most passed set targets through 2030), the European Green Deal, and ongoing work on financing mechanisms and transmission directives and programs. In the U.S., compliance with major Clean Air Act regulatory programs is likely to cause the company to incur significant capital expenditures to obtain permits, evaluate off-site impacts of its operations, install pollution control equipment, and otherwise assure compliance. Some states in which the company operates are implementing new emissions limits to comply with 2008 ozone standards regulated under the National Ambient Air Quality Standards. Pursuant to federal regulations, the company is subject to an obligation to report its GHG emissions at its largest emitting facilities, but are not generally subject to limits on emissions of GHGs. Annual reports, such as Annual Written Summary Reports for Environmental Compliance Approvals (ECAs) are submitted to the Ontario Ministry of the Environment, Conservation and Parks (MECP) and other regulators to demonstrate that the company is in good standing with its environmental requirements. History The company was founded in 1949. It was formerly known as Interprovincial Pipe Line System Inc. and changed its name to IPL Energy Inc. in 1994. Further, the company changed its name to Enbridge Inc. in 1998.