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| Company type | Crown corporation |
|---|---|
| Industry | Electric utilities |
| Founded | April 14, 1944 (1944-04-14) |
| Headquarters | Hydro-Québec Building,, Canada |
Area served | Quebec |
Key people |
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| Products | Electric power generation,electric power transmission,electricity distribution |
| Revenue |
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| Total assets |
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Number of employees |
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| Website | www |
Hydro-Québec (French pronunciation:[idʁokebɛk]) is a CanadianCrown corporationpublic utility headquartered inMontreal, Quebec. It manages thegeneration,transmission anddistribution ofelectricity in Quebec, as well as the export of power to portions of theNortheast United States. More than 40 percent ofCanada's water resources are in Quebec, and Hydro-Québec is one of the largest hydropower producers in the world.[2]
It was established as a Crown corporation by thegovernment of Quebec in 1944 from the expropriation of private firms. This was followed by massive investment in hydro-electric projects like theJames Bay Project. Today, with 63hydroelectricpower stations, the combined output capacity is 37,370 megawatts. Extra power is exported from the province and Hydro-Québec supplies 10 per cent ofNew England's power requirements.[2] The company logo, a stylized "Q" fashioned out of a circle and a lightning bolt, was designed byMontreal-based design agency Gagnon/Valkus in 1960.[3]
In 2023, it paidCA$2.47 billion individends to its soleshareholder, the Government of Quebec. Its residential power rates are among the lowest in North America.[4][non-primary source needed]
InQuebec, advocates for the creation of a public hydroelectric utility protested against high costs, poorrural electrification, and the lack of French speakers in management positions in hydroelectricity companies.[5] In 1944,Montreal Light, Heat & Power company was nationalised, along with its subsidiary, Beauharnois Power, and Hydro-Québec was created to manage the companies.
Quebec PremierAdélard Godbout adopted a policy of investing 10 million dollars per year in rural electrification.[5] However, in 1944 the government changed, and the new premierMaurice Duplessis was opposed to any form of government intervention in the economy.[6] Local cooperatives were created to bring power to rural areas.Duplessis remained in power until 1960, and during that time there were no further nationalisations of companies, and Hydro-Québec mostly served theMontreal area.
Major projects included:
Between 1944 and 1962, Hydro-Québec's installed capacity increased from 616 to 3,661 MW[7] while lowering residential power rates by half in theMontreal area.[8]
Duplessis's conservative reign, now known as theGrande Noirceur, ended when he died in office in 1959. The subsequent election of theQuebec Liberal Party, led byJean Lesage, marked the beginning of theQuiet Revolution, a period of reform and modernization. In 1962, the US government lent Quebec $300 million. The funds were used to acquire independent power companies.[10] The new government gave Hydro-Québec an exclusive mandate to develop new sites. In 1963 the government authorized it to acquire private electricity distributors, including theGatineau Power Company and theShawinigan Water & Power Company Hydro-Québec achieved province-wide scope.[11] All of the 46 rural coops accepted Hydro-Québec's 1963 buyout offer, except Saint-Jean-Baptiste-de-Rouville which still exists. In 1964, the Province of British Columbia provided the Province of Quebec with a $100 million loan. $60 million from that loan went to Hydro-Québec. The loan faced controversy in the Quebec legislature.[10] Major projects during this period included:
Because of the economic climate, demand for electricity dropped significantly in the early 1980s, which led to structural changes at Hydro-Québec. It became ajoint stock company whose sole shareholder isGovernment of Québec, to which it pays an annual dividend. It was also given the mandate to export power and to work in any energy-related field.[17]
In 1986 theQuebec – New England Transmission began bringing power from theJames Bay Project 1,100 kilometers (700 miles) south to the Boston area.
Phase II of theJames Bay Project started in 1987 and took nine years to complete. Construction of theDenis-Perron Dam began in 1994.
Like its counterparts in the North American utility industry, Hydro-Québec was reorganized in the late 1990s to comply with electricityderegulation in the United States. The transmission division,TransÉnergie, was the first to be spun off in 1997, in response to the U.S.Federal Energy Regulatory Commission's publication of Order 888.[18] In the same year, the U.S.Federal Energy Regulatory Commission granted Hydro-Québec a licence to sell wholesale electricity at market prices, enabling Hydro-Québec to expand its market. Hydro-Québec also acquired a substantial share ofNoverco, controller of natural gas distributorÉnergir, to participate in that market in northeastern North America.[19]
In 2002 theAgreement Respecting a New Relationship Between the Cree Nation and the Government of Quebec between theGrand Council of the Crees and the Quebec government made possible the development of theEastmain Reservoir. TheEastmain-1-A andSarcelle powerhouses andRupert River diversion project were completed for $5,000 million CAD. This will provide water power to the turbines atEastmain-1,Eastmain-1-A andSarcelle powerhouses and will provide increased flow at the existingLa Grande-1 generating station as well asRobert-Bourassa and theLa Grande-2-A generator stations.[20] Output will be 918 MW.
Other stations commissioned since 1997 are:[21]
In 1988, all of Quebec and parts ofNew England andNew Brunswick lost power because of an equipment failure at a substation on theNorth Shore. TheMarch 1989 geomagnetic storm trippedcircuit breakers on the transmission network causing a nine-hour Quebec-wide blackout.
In theNorth American ice storm of 1998, five days offreezing rain collapsed 600 kilometres (370 mi) ofhigh voltage power lines and over 3,000 kilometres (1,900 mi) of medium andlow voltage distribution lines in southern Quebec. Up to 1.4 million customers were without power for up to five weeks.
Hydro-Québec has created separatebusiness units dealing with thegeneration,transmission,distribution and construction. In 2017, production division generated 1.9B $ of net income (68.4%), transmission division 0.55B$ (19.4%), distribution division 0.33B $ (11.7%), and construction division did not generate any income. Hydro-Quebec redistributes all profits back to the government. In 2017, the crown corporation contributed $4 billion to the Quebec government by means of net income ($2.8B), royalties ($0.7B), public utilities tax ($0.3B) and debt securities ($0.2B).[22]
In the year 2000 with the adoption of Bill 116, which amended theAct respecting the Régie de l'énergie,[23] to enact the functional separation of Hydro-Québec's various business units. Legislation passed in 2000 commits the generation division, Hydro-Québec Production, to provide the distribution division, Hydro-Québec Distribution, a yearlyheritage pool of up to 165 TWh of energy plus ancillary services—including an extra 13.9 TWh for losses and a guaranteed peak capacity of 34,342 MW[24]—at a set price of 2.79¢ per kWh. Order in council 1277-2001 specifies quantities to be delivered for each of the 8,760 hourly intervals, which vary from 11,420 to 34,342 MW.[25]
According to the 2017 annual report the workforce stood at 19,786 employees, both permanent and temporary workers. And, a total of 1,304 employees were hired.[26]
In 1981, theParti Québécois government redefined Hydro-Québec's mission by modifying the terms of thesocial pact of 1944. The government issued itself 43,741,090 shares worth C$100 each,[27] and the amended statute stated that Hydro-Québec would now pay up to 75% of its net earnings in dividends.[28] This amendment to theHydro-Québec Act started an episodic debate on whether Hydro-Québec should be fully or partially privatized. In recent years, economist Marcel Boyer and businessman Claude Garcia—both associated with theconservative think tankThe Montreal Economic Institute—have often raised the issue, claiming that the company could be better managed by the private sector and that the proceeds from a sale would lowerpublic debt.[29][30]
Without going as far as Boyer and Garcia,Mario Dumont, the head of theAction démocratique du Québec, briefly discussed the possibility of selling a minority stake of Hydro-Québec during the2008 election campaign.[31] ALéger Marketing poll conducted in November 2008 found that a majority of Quebec respondents (53%) were opposed to his proposal to sell 7.5% of the company'sequity to Quebec citizens and businesses, while 38% were in favour.[32]
Commenting on the issue onGuy A. Lepage'stalk show, former PQ Premier Jacques Parizeau estimated that such an idea would be quite unpopular in public opinion, adding that Hydro-Québec is often seen by Quebecers as a national success story and a source of pride.[33] This could explain why various privatization proposals in the past have received little public attention. The liberal government has repeatedly stated that Hydro-Québec is not for sale.[34]
Like many other economists,[35][36] Yvan Allaire, fromMontreal's Hautes études commerciales business school, advocate increased electricity rates as a way to increase the government's annual dividend without resorting to privatization.[37] Others, like columnist Bertrand Tremblay ofSaguenay'sLe Quotidien, claim that privatization would signal a drift to the days when Quebec's natural resources were sold in bulk to foreigners at ridiculously low prices. "For too long, Tremblay writes, Quebec was somewhat of a banana republic, almost giving away its forestry and water resources. In turn, those foreign interests were exporting our jobs associated with the development of our natural resources with the complicity of local vultures".[38]
Left-wing academics, such asUQAM's Léo-Paul Lauzon and Gabriel Sainte-Marie, have claimed that privatization would be done at the expense of residential customers, who would pay much higher rates. They say that privatization would also be a betrayal of the social pact between the people and its government, and that the province would be short-selling itself by divesting of a choice asset for a minimal short term gain.[39][40]
On December 31, 2013, Hydro-Québec Production owned and operated 61hydro plants —including 12 of over 1,000 MW capacity — with 26 major reservoirs.[42] These facilities are located in 13 of Quebec's 430watersheds,[43] including theSaint Lawrence,Betsiamites,La Grande,Manicouagan,Ottawa,Outardes, andSaint-Maurice rivers.[44] These plants provide the bulk of electricity generated and sold by the company.
Non-hydro plants included thebaseload 675-MW grossGentilly nuclear generating station, aCANDU-design reactor which was permanently shut down on December 28, 2012[45] the 660-MWTracy Thermal Generating Station, a heavy fuel oil-fired plant shutdown in March 2011[46] and twogas turbinepeaker plants, for a total installed capacity of 36,971 MW in 2011.[47] Hydro-Québec's average generation cost was 2.11 cents per kWh in 2011.[48]
The company also purchases the bulk of the output of the 5,428-MWChurchill Falls generating station in Labrador, under a long-term contract that would be extended under a new agreement to 2075, if the agreement is ratified.[49] In 2009, Hydro-Québec bought the 60% stake owned byAbitibiBowater in theMcCormick plant (335 MW), located at the mouth of the Manicouagan River nearBaie-Comeau, for C$616 million.[50]
| Plant | River | Capacity (MW) |
|---|---|---|
| Robert-Bourassa | La Grande | 5,616 |
| La Grande-4 | La Grande | 2,779 |
| La Grande-3 | La Grande | 2,417 |
| La Grande-2-A | La Grande | 2,106 |
| Beauharnois | Saint Lawrence | 1,864 |
| Manic-5 | Manicouagan | 1,596 |
| La Grande-1 | La Grande | 1,436 |
| René-Lévesque | Manicouagan | 1,326 |
| Jean-Lesage | Manicouagan | 1,229 |
| Bersimis-1 | Betsiamites | 1,178 |
| Manic-5-PA | Manicouagan | 1,064 |
| Outardes-3 | aux Outardes | 1,026 |
| Others (49 hydro, 1 thermal) | 13,302 | |
| Total Hydroelectric power capacity | 36,885 | |
In 2023, the energy sold by Hydro-Québec to its grid-connected customers in Quebec and exported to neighboring markets came almost exclusively from renewable sources. Hydro (98.53%) is by far the largest source, followed by wind (0.11%) and biomass,biogas and waste (0.01%).[1] In 2013, emissions of carbon dioxide (1,130 tonnes/TWh),sulfur dioxide (4 tonnes/TWh) andnitrogen oxides (10 tonnes/TWh) were between 49 and 238 times lower than the industry average in northeastern North America. Imported electricity bought on the markets account for most of these emissions.[41]
Hydro-Québec's expertise at building and operating a very high voltage electrical grid spreading over long distances has long been recognized in the electrical industry.[51][52] TransÉnergie, Hydro-Québec's transmission division, operates the largest electricity transmission network in North America. It acts as the independent system operator and reliability coordinator for theQuébec interconnection of theNorth American Electric Reliability Corporation system, and is part of theNortheast Power Coordinating Council (NPCC). TransÉnergie manages the flow of energy on the Quebec network and ensures non-discriminatory access to all participants involved in the wholesale market.[53] The non-discriminatory access policy allows a company such asNalcor to sell some of its share of power from Churchill Falls and from other sources on the open market in the State of New York using TransÉnergie's network, upon payment of a transmission fee.[54][55]
In recent years, TransÉnergie'sContrôle des mouvements d'énergie (CMÉ) unit has been acting as the reliability coordinator of the bulk electricity network for Quebec as a whole, under a bilateral agreement between the Régie de l'énergie du Québec and theFederal Energy Regulatory Commission of the United States.[56]
TransÉnergie's high voltage network stretches over 33,630 km (20,900 mi), including 11,422 km (7,097 mi) of765 and 735 kV lines, and a network of 514 substations.[57] It is connected to neighbouring Canadian provinces and the United States by 17 ties, with a maximum reception capacity of 10,850 MW[note 1] and a maximum transmission capacity of 7,994 MW.[58]
The TransÉnergie's network operates asynchronously from that of its neighbours on theEastern Interconnection. Although Quebec uses the same 60hertz frequency as the rest of North America, its grid does not use the same phase as surrounding networks.[59] TransÉnergie mainly relies onback to back HVDC converters to export or import electricity from other jurisdictions.
This feature of the Quebec network allowed Hydro-Québec to remain unscathed during theNortheast Blackout of August 14, 2003, with the exception of 5 hydro plants on theOttawa River radially connected to the Ontario grid at the time.[60] A new 1250-MW back to back HVDC tie has been commissioned at the Outaouais substation, inL'Ange-Gardien, near theOntario border. The new interconnection has been online since 2009 and the 315 kV line is fully operational since 2010.[59]
One drawback of the TransÉnergie network involves the long distances separating the generation sites and the main consumer markets. For instance, theRadisson substation links the James Bay project plants to the Nicolet station nearSainte-Eulalie, south of the Saint Lawrence, over 1,200 kilometres (750 mi) away.[61]
 | This section needs to beupdated. Please help update this article to reflect recent events or newly available information.(March 2025) |
In 2011, TransÉnergie invested C$1.3 billion in capital expenditures, including C$460 million to expand its network.[62]
In addition to the new tie with Ontario, the company plans to build a new 1200-MW direct current link between the Des Cantons substation atWindsor, Quebec in Quebec'sEastern Townships andDeerfield, New Hampshire, with an HVDC converter terminal built atFranklin, New Hampshire.[63] The US segment of the US$1.1 billion line,[64] would be built byNorthern Pass Transmission LLC, a partnership betweenNortheast Utilities (75%) andNSTAR (25%).[65] In order to go ahead, the project must receive regulatory approval in Quebec and the United States. The proposed transmission line could be in operation in 2015.[66] According to Jim Robb, a senior executive from Northeast Utilities,New England could meet one third of itsRegional Greenhouse Gas Initiative commitments with the hydropower coming through this new power line alone.[67]
Hydro-Québec Distribution is in charge of retail sales to most customers in Quebec. It operates a network of 112,089 kilometres (69,649 mi) of medium andlow voltage lines.[68] The division is the sole electric distributor across the province, with the exception of 9 municipal distribution networks — inAlma,Amos,Baie-Comeau,Coaticook,Joliette,Magog,Saguenay,Sherbrooke andWestmount—and the electric cooperative ofSaint-Jean-Baptiste de Rouville.[69]
Hydro-Québec Distribution buys most of its power from the 165-TWhheritage pool provided by Hydro-Québec Production at 2.79¢/kWh. The division usually purchases additional power by entering into long-term contracts after a public call for tenders. For shorter term needs, it also buys power from the neighboring systems at market prices. As a last resort, Hydro-Québec Production can also provide short-term relief.[70] Supply contracts above and beyond the heritage pool must be approved by theRégie de l'énergie du Québec and their costs are passed on to customers.
The division signed onenatural gascogeneration agreement for 507 MW in 2003, three forest biomass deals (47.5 MW) in 2004 and 2005, and ten contracts forwind power (2,994 MW) in 2005 and 2008, all with private sector producers. It also signed two flexible contracts with Hydro-Québec Production (600 MW) in 2002.[71]
Hydro-Québec Distribution is also responsible for the production of power in remote communities not connected to the main power grid. The division operates an off-grid hydroelectric dam serving communities on theLower North Shore and 23 small diesel power plants in theMagdalen Islands, inHaute-Mauricie and inNunavik.
In April 2011 thegovernment of Quebec published a plan to encourage the adoption of electric vehicles, setting a target of 25% of cars sold in 2020 to be electric. The plan also called for provincial utility company Hydro-Quebec to develop a strategy for the deployment of public charging infrastructure.[72] This resulted in the creation of "The Electric Circuit" (French:Le Circuit Électrique), the largest public network ofcharging stations forelectric vehicles inQuebec.[73] The first 30 charging stations were put into use in March 2012.[74][75] The network's first 400V fast charger was installed in 2013.[76]
As of 2023, The Electric Circuit offers almost 3,500 public charging stations in Quebec andeastern Ontario.[1] Usage is also compatible with the FLO andNew Brunswick E-charge network adaptors.[citation needed]
Hydro-Québec has made significant investments in research and development over the past 40 years. In addition to funding university research, the company is the only electric utility in North America to operate its own large-scale research institute, L'Institut de recherche d'Hydro-Québec (IREQ). Established byLionel Boulet in 1967, the research centre is located inVarennes, a suburb on theSouth Shore ofMontreal.[77] IREQ operates on an annual research budget of approximately C$100 million[78] and specializes in the areas of high voltage,mechanics and thermomechanics, network simulations and calibration.[79]
Research conducted by scientists and engineers at IREQ has helped to extend the life of dams, improvewater turbine performance, automate network management and increase the transmission capacity of high voltage power lines.[80]
Another research centre, theLaboratoire des technologies de l'énergie (LTE) in Shawinigan, was opened in 1988[81] to adapt and develop new products while helping industrial customers improve theirenergy efficiency.[82]
In the last 20 years, the institute has also conductedresearch and development work towards theelectrification of ground transportation. Current projects includebattery materials, including innovative work onlithium iron phosphate and nano-titanate,[83] improved electricdrive trains and the effects of the large-scale deployment of electric vehicles on thepower grid.[84] Projects focus on technologies to increaserange, improve performance in cold weather and reducecharging time.[85]
Hydro-Québec has been criticized for not having taken advantage of some of its innovations. An electricwheel motor concept that struck a chord with Quebecers,[86] first prototyped in 1994 by Pierre Couture, an engineer andphysicist working at IREQ, is one of these.[87][88] The heir to the Couture wheel motor is now marketed byTM4 Electrodynamic Systems, a spin-off established in 1998[89] that has made deals with France'sDassault andHeuliez to develop an electric car, theCleanova, of which prototypes were built in 2006.[90] Hydro-Québec announced in early 2009 at theMontreal International Auto Show that its engine had been chosen byTata Motors to equip a demonstration version of itsIndica model, which will be road tested inNorway.[91][92]
The Hydro-Québec Équipement division acts as the company's main contractor on major construction sites, with the exception of work conducted on the territory covered by theJames Bay and Northern Quebec Agreement, which are assigned to theSociété d'énergie de la Baie James subsidiary.
The construction of a complex of four hydroelectric generating stations on the Romaine River (1,550 MW) began on May 13, 2009.[93] The plants have been completed as of 2022 and have added a total of 1 550 MW of power.[citation needed]
In his March 2009inaugural speech, Quebec PremierJean Charest announced that his government intends to further develop the province's hydroelectric potential.[94] The call for further development of hydroelectric and other renewable generating capacity has been implemented in the company's 2009-2013 strategic plan, released on July 30, 2009. Hydro-Québec plans capacity upgrades at theJean-Lesage (120 MW) andRené-Lévesque (210 MW) stations and a third unit at the SM-3 plant (440 MW). The company will also conduct technical and environmental studies and undertake consultations with local communities to build new facilities on theLittle Mecatina (1,200 MW) andMagpie (850 MW) rivers on the North Shore, and revive the Tabaret project (132 MW) in theAbitibi-Témiscamingue region, in western Quebec.[95]
Hydro-Québec first forays outside its borders began in 1978. A new subsidiary, Hydro-Québec International, was created to market the company's know-how abroad in the fields of distribution, generation and transmission of electricity. The new venture leveraged the existing pool of expertise in the parent company.[96]
During the next 25 years, Hydro-Québec was particularly active abroad with investments in electricity transmission networks and generation: Transelec inChile,[97] theCross Sound Cable in theUnited States,[52] the Consorcio Transmantaro inPeru, Hidroelectrica Rio Lajas inCosta Rica,Murraylink inAustralia and theFortuna generating station inPanama.[98]
It briefly held a 17% share in SENELEC,Senegal's electric utility, when the Senegalese government decided to sell part of the company to a consortium led by the French company Elyo, a subsidiary ofGroup Suez Lyonnaise des Eaux, in 1999.[99] The transaction was canceled in 2000 following the election of presidentAbdoulaye Wade.[100]
Also in 1999, Hydro-Québec International acquired a 20% stake in the Meiya Power Company inChina for C$83 million.[99] The company held this participation until July 2004.[101] The company's expertise was sought by several hydroelectric developers throughout the world, including theThree Gorges Dam, where Hydro's employees trained Chinese engineers in the fields of management, finance and dams.[102]
Hydro-Québec gradually withdrew from the international business between 2003 and 2006, and sold off all of its foreign investments for a profit. Proceeds from these sales were paid to the government's Generations Fund, a trust fund set up by the province to alleviate the effect of public debt on future generations.[103]
In 2022, Hydro-Québec, through its US Subsidiary HQI US Holding, acquired Great River Hydro, LLC. for the sum of US$2.2 billion.[104]
The construction and operation of electric generation, transmission and distribution facilities has environmental effects. Hydroelectric development affects the natural environment where facilities are built and on the people living in the area. The development of new reservoirs increases the level of mercury in lakes and rivers, which works up the food chain.[106] It temporarily increases the emission ofgreenhouse gases from reservoirs[107] and contributes to shoreline erosion.
Hydroelectric facilities can transform the human environment. They create new obstacles to navigation, flood traditional hunting and trapping grounds, force people to change eating habits due to the elevated mercury content of some fish species, destroy artifacts related to historic human presence on the territory, and disrupt the society and culture of Aboriginal people living near the facilities.
Since the early 1970s, Hydro-Québec has been aware of the environmental externalities of its operations. The adoption of a Quebec statute on environmental quality in 1972, the cancellation of Champigny Project, a plannedpumped storage plant in theJacques-Cartier River valley in 1973, and the James Bay negotiations leading to theJames Bay and Northern Quebec Agreement in 1975, forced the company to reconsider its practices.[108]
To address environmental concerns, Hydro-Québec established an environmental protection committee in 1970 and an Environmental Management unit in September 1973.[109] Its mandate is to study and measure the environmental effects of the company, prepare impact assessment, and develop mitigation strategies for new and existing facilities, while conducting research projects in these areas, in cooperation with the scientific community.
In the late 1970s, the company set up a network of 27 monitoring stations to measure the effects of the James Bay Project[111] which provide a wealth of data on northern environments. The first 30 years of studies in the James Bay area have confirmed that mercury levels in fish increase by 3 to 6 times over the first 5 to 10 years after the flooding of a reservoir, but then gradually revert to their initial values after 20 to 30 years. These results confirm similar studies conducted elsewhere in Canada, the United States and Finland.[110] Research also found that it is possible to reduce human exposure to mercury even when fish constitutes a significant part of a population's diet. Exposure risks can be mitigated without overly reducing the consumption of fish, simply by avoiding certain species and fishing spots.[110]
Despite the fact that the transformation of terrestrial environments into aquatic ones constitutes a major change and that flooding leads to the displacement or death of nonmigratory animals, the riparian environments lost through flooding are partially replaced by new ones on the exposed banks of reduced-flow rivers. The biological diversity of reservoir islands is comparable to other islands in the area and the reservoirdrawdown zone is used by a variety of wildlife. The population of migratory species of interest such as thecaribou have increased to the point where the hunt has been expanded.[112]
Emissions of greenhouse gases (GHG) rise significantly for a few years after reservoir impoundment, and then stabilize after 10 years to a level similar to that of surrounding lakes.[107] Gross GHG emissions of reservoirs in the James Bay area fluctuate around 30,000 tonnes of CO2 equivalent per TWh of generated power.[113] Hydro-Québec claims its hydroelectric plants release 35 times less GHG than comparable gas-fired plants and 70 times less than coal-fired ones and that they constitute the "option with the best performance" overall.[107]
Major environmental concerns relates to the human population of areas affected by hydroelectric development, specifically theInnu of the North Shore and theCree andInuit in Northern Quebec. The hydroelectric developments of the last quarter of the 20th century have accelerated the settling process among Aboriginal populations that started in the 1950s. Among the reasons cited for the increased adoption of a sedentary lifestyle among these peoples are the establishment of Aboriginal businesses, the introduction of paid labor, and the flooding of traditional trapping and fishing lands by the new reservoirs, along with the operation of social and education services run by the communities themselves under theJames Bay and Northern Quebec Agreement.[112]
Some native communities, particularly the Crees, have come to a point "where they increasingly resemble the industrialized society of the South", notes a Hydro-Québec report summarizing the research conducted in the area between 1970 and 2000. The report adds that a similar phenomenon was observed after the construction of roads and hydroelectric plants near isolated communities in northern Canada and Scandinavia. However, growing social problems and rising unemployment have followed the end of the large construction projects in the 1990s. The report concludes that future economic and social development in the area "will largely depend on the desire for cooperation among the various players".[112]
After the strong rejection of the Suroît project and its subsequent cancellation in November 2004, Hydro-Québec, under the leadership of its new CEOThierry Vandal, reaffirmed Hydro-Québec's commitment towards energy efficiency, hydropower and development of alternative energy.[114] Since then, Hydro-Québec regularly stresses three criteria for any new hydroelectric development undertaken by the company: projects must be cost effective, environmentally acceptable and well received by the communities.[70] Hydro-Québec has also taken part in a series ofsustainable development initiatives since the late 1980s. Its approach is based on three principles: economic development, social development and environmental protection.[115] Since 2007 the company adheres to theGlobal Reporting Initiative,[116] which governs the collection and publication of sustainability performance information. The company employs 250 professionals and managers in the environmental field and has implemented anISO 14001-certified environmental management system.[117]
TheInnu Nation filed a $4 billion claim against Hydro-Québec in October 2020 to receive compensation for damages caused by theChurchill Falls Generating Station.[118]
| Number of customers | Sales in Quebec (GWh) | Revenue (C$M) | Average annual consumption (kWh) | |||||
|---|---|---|---|---|---|---|---|---|
| 2011 | 2010 | 2011 | 2010 | 2011 | 2010 | 2011 | 2010 | |
| Residential and farm | 3,746,397 | 3,698,169 | 62,748 | 59,534 | 4,536 | 4,302 | 16,857 | 16,205 |
| General and institutional | 291,212 | 300,163 | 33,569 | 33,865 | 2,599 | 2,648 | 113,529 | 113,347 |
| Industrial | 18,573 | 9,589 | 67,621 | 68,439 | 3,262 | 3,185 | 4,802,287 | 7,049,027 |
| Others | 4,013 | 3,868 | 6,028 | 7,647 | 323 | 371 | 1,529,755 | 2,033,506 |
| Total | 4,060,195 | 4,011,789 | 169,966 | 169,495 | 10,720 | 10,506 | ||
At the end of 2010, Hydro-Québec served 4,060,195 customers[119] grouped into three broad categories: residential and farm (D Rate), commercial and institutional (G Rate) and industrial (M and L rates). TheOther category includes public lighting systems and municipal distribution systems.
About a dozen distribution rates are set annually by theRégie de l'énergie after public hearings. Pricing is based on the cost of delivery, which includes the cost of supply and transmission, depreciation on fixed assets and provisions for the maintenance of facilities, customer growth and a profit margin.
Rates are uniform throughout Quebec and are based on consumer type and volume of consumption. All rates vary in block to mitigate any cross-subsidization effect between residential, commercial and industrial customers.
Hydro-Québec retail rates are among the lowest in North America.[120] After a five-year rate freeze, between May 1, 1998 and January 1, 2004,[121] theRégie granted rate increases on 8 occasions between 2004 and 2010 for a total of 18.4%.[122] More recently, the regulator ordered two successive rate rollbacks in 2011 (0.4%) and 2012 (0.5%). However, rates are expected to go up by 3.7% a year from 2014 to 2018 to reflect a gradual increase of heritage pool electricity announced in the 2010 Quebec budget.[123]
The average consumption of residential and agricultural customers is relatively high, at 16,857 kWh per year in 2011,[119] because of the widespread use of electricity as the main source ofspace (77%) andwater heating (90%).[124] Hydro-Québec estimates that heating accounts for more than one half of the electricity demand in the residential sector.[125]
This preference for electric heating makes electricity demand more unpredictable, but offers some environmental benefits. Despite Quebec's very cold climate in winter,greenhouse gases emissions in the residential sector accounted for only 5.5% (4.65 MtCO
2 eq.) of all emissions in Quebec in 2006. Emissions from the residential sector in Quebec fell by 30% between 1990 and 2006.[126]
Residential use of electricity fluctuates from one year to another, and is stronglycorrelated with the weather. Contrary to the trend in neighboring networks, Hydro-Québec's system is winter-peaking. A new all-time consumption record was set on January 23, 2013 with a load of38,910 MW.[127] Previous records were established on January 24, 2011 with37,717 MW, on January 16, 2009, with a load of37,230 MW,[128][129] and on January 15, 2004 when peak reached36,268 MW.[130]
The price of electricity for residences and farms includes a 40.64¢ daily subscription fee, and two price levels depending on consumption. The rates are all-included: power, transmission and distribution costs, but are subject to theGoods and Services Tax (GST) and theQuebec Sales Tax (QST).[131] As of April 1, 2012, customers pay 5.32¢/kWh for the first 30 daily kWh, while the remainder is sold at 7.51¢/kWh.[132] The average monthly bill for a residential customer was approximately C$100 in 2008.[133]
Electric meter readings are usually conducted every two months and bills are bimonthly. However, the company offers an optionalEqualized Payment Plan allowing residential customers to pay their annual electricity costs in 12 monthly installments, based on past consumption patterns of the current customer address and the average temperature in that location.[134]
In 2007, Hydro-Québec pulled out of a Canadian government initiative to installsmart meters across the province, stating that it would be "too costly to deliver real savings".[135] Since then, Hydro-Québec organized a 2-year pilot project, involving 2,000 customers in 4 cities, withtime of use metering. A report, filed with theRégie de l'énergie, in the summer of 2010 concluded that the effect ofmarginal cost pricing with three levels of pricing in the winter would lead to minimal load and energy savings.[136] The company intends to gradually phase-inAdvanced Metering Infrastructure (AMI) between 2011 and 2017. Early efforts will focus on meter data transfer, connect-disconnect, outage detection and theft reduction.[137]
For more than a century, industrial development in Quebec has been stimulated by the abundance of hydroelectric resources. Energy represents a significant expenditure in the pulp and paper and aluminum sectors. two industries with long-standing traditions in Quebec. In 2010, industrial customers purchased 68.4 TWh from Hydro-Québec, representing 40.4% of all electricity sold by the company on the domestic market.[138]
The Quebec government uses low electricity rates to attract new business and consolidate existing jobs. Despite its statutory obligation to sell electric power to every person who so requests, the province has reserved the right to grant large load allocations to companies on a case-by-case basis since 1974. The threshold was set at 175 MW from 1987 to 2006[139] and was reduced to 50 MW in the government's 2006–2015 energy strategy.[140]
Large industrial users pay a lower rate than the domestic and commercial customers, because of lower distribution costs. In 2010, the largest industrial users, theRate L customers, were paying an average of 4.66¢/kWh whereas companies with special contracts paid 3.07¢/kWh.[141]
In 1987, Hydro-Québec and the Quebec government agreed to a series of controversial deals withaluminum giantsAlcan andAlcoa. These risk sharing contracts set the price of electricity based on a series of factors, including aluminum world prices and the value of theCanadian dollar[142] Those agreements are gradually being replaced by one based on published rates.
On May 10, 2007, the Quebec government signed an agreement with Alcan. The agreement, which is still in force despite the company's merger withRio Tinto, renews the water rights concession on the Saguenay and Peribonka rivers. In exchange, Alcan has agreed to invest in its Quebec facilities and to maintain jobs and its corporate headquarters in Montreal.[143]
On December 19, 2008, Hydro-Québec and Alcoa signed a similar agreement. This agreement, which expires in 2040, maintains the provision of electricity to Alcoa's threealuminum smelters in the province, located inBaie-Comeau,Bécancour andDeschambault-Grondines. In addition, the deal will allow Alcoa to modernize the Baie-Comeau plant which will increase its production capacity by 110,000 tonnes a year, to a total of 548,000 tonnes.[144]
Several economists, includingUniversité Laval's Jean-Thomas Bernard and Gérard Bélanger, have challenged the government's strategy and argue that sales to large industrial customers are very costly to the Quebec economy. In an article published in 2008, the researchers estimate that, under the current regime, a job in a new aluminum smelter or an expansion project costs the province between C$255,357 and C$729,653 a year, when taking into consideration the money that could be made by selling the excess electricity on the New York market.[145]
This argument is disputed by large industrial customers, who point out that data from 2000 to 2006 indicate that electricity exports prices get lower when quantities increase, and vice versa. "We find that the more we export, the less lucrative it gets", said Luc Boulanger, the head of the association representing Quebec's large industrial customers. In his opinion, the high volatility of electricity markets and the transmission infrastructure physical limitations reduce the quantities of electricity that can be exported when prices are higher.[146]
Hydro Quebec gained attention withBitcoin miners in 2018 after the crackdown on mining in China.[147] The province has an energy surplus equivalent to 10 Terawatt hours per year.[147]
 | This articleis missing information about plans on construction of a line connecting the Hydro-Québec system to Maine. Please expand the article to include this information. Further details may exist on thetalk page.(March 2021) |
| 2023 | 2022 | 2021 | 2020 | 2019 | |
|---|---|---|---|---|---|
| Exports (TWh)[note 2] | 23.0 | 35.6 | 36.2 | 32.4 | 34.8 |
| Revenue ($M) | 2,365 | 2,912 | 1,826 | 1,466 | 1,571 |
Hydro-Québec sells part of its surplus electricity to neighbouring systems in Canada and the United States under long-term contracts and transactions on the New England, New York and Ontariobulk energy markets. In 2017, net exports revenues were at $1,651 million for a total of 34.4 TWh sent to New England (53%), New York (23%), Ontario (13%) and other (5%).[148][149]
Although most export sales are now short-term transactions, Hydro-Québec has entered into long-term export contracts in the past. The corporation has 15 interconnections to neighboring markets. In 1990, the company signed a 328-MW deal with a group of 13 electric distributors inVermont. On March 11, 2010, Vermont's two largest utilities, Green Mountain Power and Central Vermont Public Service, entered into a tentative 26-year deal with Hydro-Québec to purchase up to 225 MW of hydro power from 2012 to 2038. The memorandum of understanding provides for a price smoothing mechanism shielding Vermont customers from market price spikes. The deal is contingent upon the enactment designating large hydro as "renewable energy".[150]
In 2015, Hydro-Quebec and the Ontario Independent Electricity System Operator (IESO) signed a 500-MW seasonal capacity sharing agreement. Ontario has increased capacity in the Winter, and shortages in the summer. Quebec has increased capacity in the summer, and shortages in the Winter. Thus, the agreement serves as to achieve a cost-effective solution for both provinces. Furthermore, in 2016 (IESO) and Hydro-Quebec signed a new long-term agreement starting in 2017 until 2023. The deal will send 2TWh per year to Ontario. On the other hand, Quebec should receive capacity from Ontario during Winter's peak demand.[151]
| Rank | Name | Nomination date |
|---|---|---|
| 1st | Télesphore-Damien Bouchard | April 15, 1944 |
| 2nd | L.-Eugène Potvin | June 29, 1944 |
| 3rd | J.-Arthur Savoie | June 1, 1955 |
| 4th | Jean-Claude Lessard | September 7, 1960 |
| 5th | Roland Giroux | August 1, 1969 |
| 6th | Robert A. Boyd | 1977 |
| 7th | Lucien Saulnier | 1978 |
| 8th | Guy Coulombe | January 15, 1982 |
| 9th | Richard Drouin | May 2, 1988 |
| 10th | Yvon Martineau | 1995 |
| 11th | Benoît Michel | December 1, 1995 |
| 12th | André Caillé | October 1, 1996 |
| 13th | Thierry Vandal | April 5, 2005 |
| 14th | Éric Martel | June 3, 2015 |
| 15th | Sophie Brochu | April 1, 2020 |
| 16th | Michael Sabia | August 1, 2023 |
| 17th | Claudine Bouchard | July 5, 2025 |
From 1944 to 1978, management of Hydro-Québec consisted of five commissioners, one of them acting as president.
In addition to the long-standing focus on large-scale transmission expansion, contemporary research—such as that presented by Gazaret al. (2024)[154]—has investigated the causal relationships between cross-border transmission capacity, new hydroelectric generation, and evolving energy demand in the northeastern United States and Canada. Their Bayesian network analysis suggests that increases in Quebec's hydroelectric capacity historically correlate more strongly with domestic demand and market price signals, rather than simply the availability of expanded transmission corridors. These findings can inform discussions of whether newly proposed U.S.–Canada intertie projects should include upstream reservoir development in environmental impact assessments.
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