Hydro-Québec's electricity transmission system

Hydro-Québec's electricity transmission system (also known as the Quebec interconnection) is an international power transmission system centred in Quebec, Canada. The system pioneered the use of very high voltage 735 kV alternating current (AC) power lines that link the population centres of Montreal and Quebec City to distant hydroelectric power stations like the Daniel-Johnson Dam and the James Bay Project in northwestern Quebec and the Churchill Falls Generating Station in Labrador (which is not part of the Quebec interconnection).

The two major and three minor NERC interconnections, and the nine NERC Regional Reliability Councils.
735 kV substation near the Robert-Bourassa generating station

The system contains more than 34,187 kilometres (21,243 mi) of lines and 530 electrical substations. It is managed by Hydro-Québec TransÉnergie, a division of the crown corporation Hydro-Québec and is part of the Northeast Power Coordinating Council. It has 17 interconnections with the systems in Ontario, Newfoundland and Labrador, New Brunswick, and the Northeastern United States and 6,025 MW of interconnection import capacity and 7,974 MW of interconnection export capacity.[1]

Major expansion of the network began with the commissioning of the 735 kV AC power line in November 1965, as there was a need for electricity transmission over vast distances from the north to southern Quebec.

Much of Quebec's population is served by a few 735 kV power lines. This contributed to the severity of the power outage following the North American ice storm of 1998. The extent and duration of this blackout has generated criticism of the transmission system, and there is controversy concerning the use of hydroelectric dams.

History
Hydro-Québec's first logo (1944–1960)

The first hydroelectric stations in Québec were built by private entrepreneurs in the late 1800s. In 1903 the first long distance high-voltage transmission line in North America was built, a 50 kV line connecting a Shawinigan powerstation to Montréal, 135 km away. In the first half of the 1900s, the market was dominated by regional monopolies, whose service was publicly criticised. In response, in 1944 the provincial government created Hydro Quebec from the expropriated Montreal Light, Heat & Power[2]

In 1963 Hydro-Québec purchased the shares of nearly all remaining privately owned electrical utilities then operating in Québec and undertook construction of the Manicouagan-Outardes hydroelectric complex. To transmit the complex's annual production of about 30 billion kWh over a distance of nearly 700 km, Hydro-Québec had to innovate. Led by Jean-Jacques Archambault, it became the first utility in the world to transmit electricity at 735 kV, rather than 300–400 kV which was the world standard at that time.[2] In 1962, Hydro-Québec proceeded with the construction of the first 735 kV power line in the world. The line, stretching from the Manic-Outardes dam to the Levis substation, was brought into service on 29 November 1965.[3]

Over the next twenty years, from 1965 to 1985, Quebec underwent a massive expansion of its 735 kV power grid and its hydroelectric generating capacity.[4] Hydro-Québec Équipement, another division of Hydro-Québec, and Société d’énergie de la Baie James built these transmission lines, electrical substations, and generating stations. Constructing the transmission system for the La Grande Phase One, part of the James Bay Project, took 12,500 towers, 13 electrical substations, 10,000 kilometres (6,000 mi) of ground wire, and 60,000 kilometres (40,000 mi) of electrical conductor at a cost of C$3.1 billion alone.[5] In less than four decades, Hydro-Québec's generating capacity went from 3,000 MW in 1963 to nearly 33,000 MW in 2002, with 25,000 MW of that power sent to population centers on 735 kV power lines.[6]

Source of the electricity

Much of the electricity generated by Hydro-Québec Generation[7] comes from hydroelectric dams located far from load centres such as Montreal. Of the 33,000 MW of electrical power generated, over 93% of that comes from hydroelectric dams and 85% of that generation capacity comes from three hydroelectric generation centers: James Bay, Manic-Outardes, and Newfoundland and Labrador Hydro's Churchill Falls.[8]

James Bay
Main article: James Bay Project
The spillway of the Robert-Bourassa Dam (formerly La Grande-2 Dam), one of many hydroelectric dams supplying power to the load centres of Montreal, Quebec City, and the Northeastern United States

The James Bay Project encompasses the La Grande project, which is located on the La Grande River and on its tributaries, such as the Eastmain River, in northwestern Quebec. The La Grande project was built in two phases; the first phase lasted twelve years from 1973 to 1985 and the second phase lasted from 1985 to present time.[9] In all, the nine hydroelectric dams there produce over 16,500 MW of electric power, with the Robert-Bourassa or La Grande-2 station generating over 5,600 MW alone.[10] In total, the project cost over C$20 billion to construct.[11]

Manic-Outardes power stations

The Manic-Outardes river area in the Côte-Nord or North Shore region consists of several hydroelectric facilities located on three principal rivers, from west to east: Betsiamites River, Rivière aux Outardes, and the Manicouagan River. A single plant named Sainte-Marguerite-3 is located to the east on the Sainte-Marguerite River (Sept-Îles).[12] The facilities located in the region were constructed over a period of five decades, from 1956 to 2005. The total generation capacity from these power stations is 10,500 MW. A 21-MW hydroelectric power station, the Lac-Robertson generating station on the Lower North Shore, is not connected to the main Quebec grid.[13]

Churchill Falls
Main article: Churchill Falls Generating Station

Churchill Falls is a single underground generation station located on the Churchill River near the town of Churchill Falls and the Smallwood Reservoir in Labrador. It was constructed over a period of five to six years from 1966 to 1971–72 by the Churchill Falls (Labrador) Corporation (CFLCo), though generators were installed after major construction was completed.[14] The single generation facility cost C$946 million to construct and produced 5,225 MW of power initially after all eleven generating units were installed.[15] A station upgrade in 1985 raised the generating capacity to over 5,400 MW.[15] Hydro-Québec Generation owns a 34.2% interest in CFLCo, which is the same company that constructed the generating plant. However, Hydro-Québec has rights to most of the 5,400 MW of power the station produces under a 65-year power purchase agreement, expiring in 2041.[16]

View of Churchill Falls, the electrical substation, and the three 735 kV lines that span the river gorge

Electricity transmission system features

The system contains more than 34,187 kilometres (21,243 mi) of lines and 530 electrical substations. It is managed by Hydro-Québec TransÉnergie, a division of the crown corporation Hydro-Québec and is part of the Northeast Power Coordinating Council. It has 17 interconnections with the systems in Ontario, New Brunswick, Newfoundland and Labrador, and the Northeastern United States and 6,025 MW of interconnection import capacity and 7,974 MW of interconnection export capacity.[1] The system has transmission lines reaching to power generation facilities located more than 1,000 kilometres (600 mi) away from population centers.[17][18][19][20] For this reason, TransÉnergie uses a voltage of AC 735 kV to transmit and distribute electrical power produced from Hydro-Québec's dams, although 315 kV is used as well.[21] The total value of TransÉnergie's entire electricity transmission system is C$15.9 billion.[22] For these reasons, Hydro-Québec TransÉnergie is considered to be a world leader in power transmission.[5]

AC 735 / 765 kV power lines
A Mae West pylon from an Hydro-Québec TransÉnergie 735 kV power line, recognizable by the x-shaped spacers separating the three 4-conductor sets.

From 1965 onwards, the 735 kV power line became an integral part of Québec's power transmission backbone. More than one-third of Hydro-Québec TransÉnergie's system consists of high voltage AC 735 / 765 kV power lines, totaling 11,422 kilometres (7,097 mi)[A] strung between 38 substations with equipment of that voltage.[22] The first transmission system from 1965 is an IEEE Milestone.[23]

The physical size of the Hydro-Québec's 735 kV transmission lines is unmatched in North America. Only two other utility companies in the same region, the New York Power Authority (NYPA) and American Electric Power (AEP) contain at least one 765 kV line in their power system.[24][25][26] However, only AEP has a significant mileage of 765 kV power lines, with over 3,400 kilometres (2,100 mi) of 765 kV line traversing its broad transmission system; this system contains the most mileage in the United States under one electrical company.[26] NYPA has only 219 kilometres (136 mi) of 765 kV line, all of it contained in a single direct interconnection with Hydro-Québec.[27][28]

The 735 kV power line is said to lessen the environmental impact of power lines, as one single power line operating at this voltage carries the same amount of electric power as four 315 kV power lines, which would require a right-of-way wider than the 80.0–91.5 metres (262.5–300.2 ft)[29][30] width required for a single 735 kV line.[17][20][26] Each 735 kV line is capable of transmitting 2,000 MW of electric power at a distance of over 1,000 kilometres (620 miles) and the entire 735 kV grid can carry 25,000 MW of power.[18] Power transmission losses over the 735 kV grid range from 4.5 to 8%, varying due to temperature and operating situations.[31] The Ordre des ingénieurs du Québec named the 735 kV power line system as the technological innovation of the 20th century for Quebec.[32]

In the wake of the 1998 ice storm the Levis De-Icer was installed and began testing in 2007 and 2008.

The Lévis substation.

Routes
Cross rope "Chainette" ("little necklace") suspension pylons used on some parts of 735 kV lines between the James Bay hydroelectric complex and Montreal.

Hydro-Québec TransÉnergie's 735 kV system consists of a set of six lines running from James Bay to Montreal and a set of four lines from Churchill Falls and the Manic-Outardes power stations to Quebec City. The South Shore region of Montreal and the Saint Lawrence River between Montreal and Quebec City contain 735 kV power line loops or rings.[27][33]

James Bay

The James Bay hydroelectric dam complex contains several relatively short 735 kV power lines that send electricity to three principal substations, ordered from west to east: Radisson, Chissibi, and Lemoyne.[34] From these substations, six 735 kV power lines[8] traverse the vast expanses of taiga and boreal forest in clear-cut stretches of land; this shows up clearly in aerial photos.[35][36] The terrain that the power lines cross is for the most part not mountainous, but smooth and replete with lakes.[33] Generally, four of the lines runs together in two pairs and the other two run solo, although the two single lines sometimes do run in a pair.[21] Two intermediate 735 kV power lines, one in the north and one in the south, connect all six power lines along their path to southern Quebec.

As the lines continue south, they diverge into two sets of three 735 kV transmission lines. The eastern set heads to Quebec City, where it connects with power lines from Churchill Falls and the 735 kV power line loops in the Saint Lawrence River region. The western set heads to Montreal, where it too forms a ring of 735 kV power lines around the city, linking to other power loops in the region.[27][33] This section of Hydro-Québec TransÉnergie's power grid contains 7,400 km (4,600 mi) of 735 kV AC and 450 kV DC power line.[11]

Manic-Outardes power stations / Churchill Falls
The Micoua substation, on Quebec's North Shore. The substation is one of TransÉnergie's transmission hubs.

Electrical power generated from the Churchill Falls power station is sent to Montreal and the population centres of the Northeastern United States, more than 1,200 kilometres (700 mi) away.[37] Starting from the generation station in Labrador, the power lines span a distance of 1,800 metres (6,000 ft) over the Churchill River gorge and run generally south-southwest for 203 kilometres (126 mi) as three side-by-side power lines in a cleared right-of-way with a width of 216 metres (709 feet).[14] As they head southwest through boreal forest, the lines generally traverse flat, smooth rolling hills.[29]

After the lines cross the Quebec-Labrador border, also known as the Hydro-Québec point of delivery,[14] the direction of the lines becomes due south, and they head to the Montagnais Substation, a substation accessible only by an airport adjacent to it. A lone 735 kV line stems off from the substation, heading to an open pit mine 142 kilometres (88 mi) the northwest. The terrain crossed by the power lines becomes hilly and mountainous south of the border. The lines reach over 800 metres (2,600 ft) in elevation before descending.[38] The three lines continue heading south until they reach a substation on the North Shore of the Gulf of Saint Lawrence. From there on, the three lines parallel the North Shore as the Gulf narrows to the southwest toward the Saint Lawrence River discharge mouth. The northernmost power line then diverges from the other two to connect with Manic-Outardes power stations located on and around the Rivière aux Outardes and the Manicouagan River.

Triple 735kV Mae West towers at Boischatel / L'Ange-Gardien limits, on Route 138 east of Quebec City, as lines crosses the St. Lawrence River south towards the Île d'Orléans.

As the lines near Quebec City, the northern power line rejoins the other two 735 kV power lines. The three lines, paralleled by another 735 kV power line some distance to the north, span over the Saint Lawrence River to the South Shore region, where the lines form loops encompassing part of the Saint Lawrence River and the south shore. The loops are also connected to the ring of 735 kV power lines around Montreal and power lines running south from James Bay.[27][33]

Electricity pylons

Quebec's transmission system contains a variety of electrical pylons depending on era and voltage level. Older pylon designs tend to consume more material than the newer pylons and the higher the voltage level, the larger the tower.[39]

735 kV pylons
Two types of single-circuit 735 kV delta pylons near Saint-Jean-sur-Richelieu paralleled by a dual-circuit 315 kV line. The center 735 kV line uses a larger version delta pylon while the one to the right uses smaller one.

Hydro-Québec TransÉnergie uses several different types of electricity pylons to support their 735 kV power lines.[5] All of them are single-circuit, meaning that each pylon carries one power line with three bundles of four electrical subconductors separated by spacers,[29] with each bundle transmitting one phase of current.

A series of V-guyed towers, near Chapais, Quebec.

The earliest type of tower used was a massive self-supporting delta pylon, or waist pylon,[39] which consumed 21 tonnes of steel per kilometre of line.[5] This type of pylon was used for the first 735 kV power line from the Manic-Outardes power stations to the load centre of Montreal.[33] There are two significant variations of the delta pylon; one has longer side crossbars such that all three bundles of conductors are suspended on V-shaped insulators.[40] The other has shorter side crossbars, such that the two outside bundles are hung on a vertical insulator string and only the middle bundle is hung with a V-shaped insulator.[41]

Over the years, Hydro-Québec researchers engineered a new type of pylon, the V-guyed tower, which reduced materials consumption to 11.8 tonnes of steel per kilometre of power line.[5] This type of tower also includes a variation with longer side crossbars, where all conductors are hung with a V-shaped insulator[42] and one with shorter side crossbar, where only the middle bundle hangs from the insulator and the side bundles are strung on vertical insulator strings.[43][44]

During the construction of the James Bay transmission system, the cross-rope suspension tower was invented.[5] This type of tower features two guyed-tower legs similar to the V-guyed tower, but the two legs don't converge at the tower base. In the case of the cross-rope suspension tower, the tower legs are spread apart on two different foundations.[35] In addition, the crossbar is replaced by a series of suspension cables with three vertical insulator strings to support the three bundles, which allows this design to consume only 6.3 tonnes of steel per kilometre of line.[5] The design is also known as the Chainette (little necklace).[45]

TransÉnergie uses two-level pylons for angle towers or structures on 735 kV power lines to change the direction of the line or switch the position of the conductor bundles.[33][40] Delta pylons and three-leg guyed towers are also used as angle towers; they are referred to as "penguins" by Hydro-Québec linemen.[35][46]

Pylons for other voltage levels

Hydro-Québec TransÉnergie uses a combination of double-circuit three-level pylons and single-circuit delta pylons to suspend electrical conductors of other voltages, such as 315 kV.[33][39][47] The ±450 kV high-voltage direct current line in Hydro-Québec's power grid uses a T-shaped tower, lattice or pole, to support two bundles of three conductors on each side. The direct current power line sometimes uses two poles or a wider, pyramidal, self-supporting lattice structure for angle towers.[33][48]

174.6 metre pylon adjacent to Hydro-Québec's now-decommissioned Tracy power plant.
Other pylons

Hydro-Québec usually uses tall, large pylons to cross large bodies of water, like lakes and rivers. These towers are said to be prominent and the tallest pylon in Hydro-Québec's power grid is of this function. The tallest of these is located near the Tracy power station on the shore of the Saint Lawrence River, carrying a 735kV circuit between Lanoraie and Tracy. The pylon, the largest of its kind in Canada, is 174.6 metres (572.8 ft) tall, the same height as the Montreal Olympic Stadium, and slightly larger than the Washington Monument in the United States (555 feet (169.2 m)).[49]

Pylon strength

The pylons and conductors are designed to handle 45 millimetres (1.8 inches) of ice accumulation without failure,[19] since Hydro-Québec raised the standards in response to ice storms in Ottawa in December 1986 and Montreal in February 1961, which left 30 to 40 millimetres (1.2 to 1.6 inches) of ice.[50][51][52] This has led to the belief that Hydro-Québec TransÉnergie's electrical pylons are "indestructible".[53] Despite being more than three times higher than the Canadian standard of only 13 millimetres (0.51 inches) of ice tolerance,[54] an ice storm in the late-1990s deposited up to 70 millimetres (2.8 inches) of ice.[19][51]

Interconnections
The Outaouais substation, the newest of 19 interconnections between Hydro-Québec's network and neighboring power grids.

Across North America, electricity transmission systems are interconnected into wide area synchronous grids, or interconnections. Suppliers are legally required to follow reliability standards. In 2006, Québec's transmission system was recognized by the North American Electric Reliability Corporation (NERC) as a full interconnection because it is asynchronous with neighboring systems. Québec will consequently be able to develop its own reliability standards, as needed, and these will apply in addition to the relevant North American standards.[55] Besides the Quebec Interconnection, there are three other interconnections in North America: the Eastern Interconnection, the Western Interconnection, and the Electric Reliability Council of Texas.

Hydro-Québec TransÉnergie has the following interconnections with systems in neighboring provinces and states:[56]

  • New York: two connections. Capacity is 1,100 MW import, 1,999 MW export.
  • Ontario: eight connections. 1,970 MW import, 2,705 MW export.
  • New England: three connections. 2,170 MW import, 2,275 MW export.
  • New Brunswick: three connections. 785 MW import, 1,029 MW export.
  • Labrador: one connection. 5,500 MW import, 0 MW export.

The maximum simultaneous delivery (export) for the interconnection common to New York and Ontario is 325 MW.

High voltage direct current (HVDC) 450 kV
Main article: Quebec – New England Transmission

In addition to the six 735 kV power lines that stem from the James Bay Project, a seventh power line was constructed as an 1,100 kilometres (680 mi) northward extension of an existing high-voltage direct current (HVDC) line connecting Quebec and New England. This power line expansion was completed in 1990. As a result, the direct current power line is unique because there are multiple static converter and inverter stations along the 1,480 kilometres (920 mi) long power line.[8] It is also the first multiterminal HVDC line in the world. The ±450 kV power line can transmit about 2,000 MW of hydroelectric power to Montreal and the Northeastern United States.[57][58][59]

Route

Beginning in the converter station next to the Radisson substation, the HVDC line heads south and roughly parallels the six 735 kV power lines some distance to the west. It traverses the same type of terrain as the other six lines; the land is replete with lakes, wetlands, and forested rolling hills.[33] Gradually, the power line turns to the southeast, as it crosses under several 735 kV power lines.

After the six 735 kV wires split up into two groups of three power lines each, the HVDC line follows the eastern group, and the western set diverges away.[21][27] The line remains overhead until it reaches the north shore of the Saint Lawrence River near Grondines, where the 450 kV HVDC line descends into an underwater tunnel traversing the river. The power line surfaces on the south shore near Lotbinière substation. After the river crossing, the line enters into the Nicolet terminal near Sainte-Eulalie, northeast of Drummondville. South of the terminal, the line heads south and after a relatively short distance, it enters the Des Cantons close to Sherbrooke.

Leaving the Des Cantons station, the power line crosses the Canada–US border and passes through the hilly Appalachian Mountains in the U.S. state of Vermont, reaching an elevation of about 650 metres (2,130 ft).[38] The line then continues heading south-southeast and enters the state of New Hampshire, where it reaches the Comerford terminal near Monroe. Continuing southward into Massachusetts, the line reaches the Sandy Pond terminal outside of Boston in Ayer.[59] The terminal is the southernmost extent of the HVDC line.[33][57]

In December 2008, Hydro-Québec, along with American utilities Northeast Utilities and NSTAR, created a joint venture to build a new HVDC line from Windsor, Quebec to Deerfield, New Hampshire.[60] Hydro-Québec will own the segment within Quebec, while the segment within the US will be owned by Northern Pass Transmission LLC, a partnership between Northeast Utilities (75%) and NSTAR (25%).[61] Estimated to cost US$1.1 billion to build,[62] it is projected that the line will either run in existing right-of-way adjacent to the HVDC line that runs through New Hampshire, or it will connect to a right-of-way in northern New Hampshire that will run through the White Mountains. This 180-to-190-mile (290 to 310 km) line, projected to carry 1,200 megawatts, will bring electricity to approximately one million homes.[63]

Other features

TransÉnergie uses series compensation to alter the way electricity behaves in power transmission lines, which improves the electricity transmission efficiency. This reduces the need to construct new power lines and increases the amount of electric power sent to population centres. Series compensation is based on capacitor technology. To maintain its transmission system performance, TransÉnergie sets aside funds for research and application of new technologies.[64] In addition to power transmission technology, Hydro-Québec plans to offer high-speed internet over its transmission lines within a few years; the utility started testing internet over its lines in January 2004.[65]

Major disruptions

In spite of the transmission system's reputation and the fact Quebec escaped unscathed from the Northeast Blackout of 2003, the system has experienced damage and service interruptions from severe storms in the past.[17][64] Examples include the 1982 and 1988 Quebec blackouts prior to the large 1989 and 1998 power interruptions.

1989 Geomagnetic storm
Main article: March 1989 geomagnetic storm

At 2:44 am EST on March 13, 1989, a severe geomagnetic storm, due to a coronal mass ejection from the Sun, struck Earth.[66][67] Fluctuations within the magnetic field of the storm caused geomagnetically induced currents (GICs) to flow through Quebec's power lines, which are direct current, instead of the alternating current carried by the power lines.[66] The insulating nature of the Canadian Shield igneous rock directed the GICs to the power lines. The conductors then forwarded this current to sensitive electrical transformers, which require a certain voltage amplitude and frequency to function properly. Although most GICs are relatively feeble, the nature of those currents destabilized the voltage of the power grid and current spikes erupted everywhere.[66]

Accordingly, protective measures were taken in response. To save the transformers and other electrical equipment, the power grid was taken out of commission, as circuit breakers tripped all over Quebec and shut off the power.[68] Within less than 90 seconds, this wave of breaking circuits left the entire transmission grid out of service. The collapsed power grid left six million people and the rest of Quebec without electricity for hours on a very cold night. Even though the blackout lasted around nine hours for most places, some locations were in the dark for days. This geomagnetic storm caused about C$10 million in damage to Hydro-Québec and tens of millions to the customers of the utility.[66]

1998 ice storm
Map showing precipitation amounts for Quebec and the Northeastern United States

From January 4/5 to January 10, 1998, warm moist air from the south overriding cold air from the north produced an ice storm, leading to over 80 hours of freezing rain and drizzle.[69][70] For days, a continuous shower of mostly freezing rain amounted to 70–110 millimetres (2.8–4.3 inches) of water equivalent of precipitation.[71] Places like Montreal and the South Shore were especially hard hit, with 100 mm (3.9 in) of largely freezing rain falling.[70] These heavy precipitation totals wreaked havoc on the regional power transmission system.

Physical damage

Five to six days of freezing rain and precipitation crippled the Hydro-Québec power grid in the Montreal and South Shore regions. In an area 100 by 250 kilometres (62 by 155 miles), some 116 transmission lines were out of commission, including several major 735 kV power lines and the Quebec–New England HVDC ±450 kV line.[72]

Damage to trees and a power distribution line

Through successive waves of freezing precipitation, more than 75 millimetres (3.0 inches) of radial ice accumulated on the electrical conductors and the pylons themselves. This ice coating adds an additional weight of 15 to 20 kilograms per metre of conductor (10 to 20 lb/ft). Even though the electrical wires can withstand this extra weight, when combined with the effects of wind and precipitation, these conductors may break and fall.[73] The pylons, designed to withstand only 45 millimetres (1.8 inches) of ice accretion, buckled and collapsed into twisted heaps of mangled steel.[52] Cascading failures occurred on several transmission lines, where the collapse of one or more towers left a row of fallen pylons.[72][74]

Of all the pylons damaged, some 150 were pylons supporting 735 kV lines,[19] and 200 towers carrying 315 kV, 230 kV, or 120 kV power lines collapsed as well.[B][72] In a region bounded by Montreal between Saint-Hyacinthe, Saint-Jean-sur-Richelieu and Granby, dubbed the "triangle of darkness", half of the overhead power grid was out of service.[75] Quebec ordered myriad conductors, crossarms, and wire connections to repair the ones disabled by the storm in the electrical transmission and electric power distribution system.[19] In all of Quebec, 24,000 poles, 4,000 transformers, and 1,000 electrical pylons were damaged or destroyed,[B] more than 3,000 km (2,000 mi) of downed electrical wires; this cost a total of C$800 million to repair.[71][73]

Power outage

With over 100 transmission lines paralyzed by the ice, Quebec fell into a massive power outage in the cold Canadian winter. Even though power restoration initiated after the first blackouts, large numbers of Quebecers were in the dark.[72] At the height of the blackout, some 1.4–1.5 million homes and customers, housing three[76] to more than four million people,[75] were in the dark.[77][78] Private companies and other utilities from other parts of Canada and the United States were sent in to help Hydro-Québec undertake this massive restoration task, but these efforts were complicated by the widespread damage of the power grid.[79] Blackouts in some areas lasted for 33 days, and 90% of those affected by the blackout had no power for more than seven days.[19][71] Although power was fully restored to all locations in Quebec by February 8, 1998, it wasn't until mid-March that the power facilities were back in service.[72] By then, much social and economic damage had occurred, such as ruined food and deaths resulting from lack of electric heating.[19]

After the power outage was over, Hydro-Québec made numerous upgrades to its system in order to improve the power grid. Examples include the strengthening of electrical pylons and power poles, and increasing the power supply. This was done to enable the utility to restore power more rapidly in the case of a massive ice striking Quebec again. Hydro-Québec has stated that it is better-prepared to handle an ice storm with the same magnitude as the one of 1998.[71]

2004 hydro tower bombing

In 2004, shortly before U.S. President George W. Bush's visit to Canada, a tower along the Quebec – New England Transmission HVDC circuit in the Eastern Townships near the Canada–US border was damaged by explosive charges detonated at its base. The CBC reported that a message, purportedly from the Résistance internationaliste and issued to the La Presse and Le Journal de Montréal newspapers and the CKAC radio station, stated that the attack had been carried out to "denounce the 'pillaging' of Quebec's resources by the United States."[80][81]

Criticism
See also: James Bay Cree hydroelectric conflict

The performance of Hydro-Québec TransÉnergie's power grid during 1998 Ice Storm raised questions about the fundamental concept, vulnerability, and reliability of the grid.[19] Critics noted that the power generation facilities were located approximately 1,000 km (600 mi) away from population centres and that there was a lack of local power stations around Montreal, which is served by only six 735 kV feeder lines.[82] In addition, the 735 kV transmission system received scorn from the public and the media. The power transmission grid was said to concentrate power transmission on only a few 735 kV lines, such as those that run from James Bay to Montreal. Out of the six 735 feeder lines in Montreal, five of them form a loop called the "ring of power" around the city. When the ring failed on January 7, 1998, roughly 60% of Greater Montreal's power supply was offline.[75] Hydro-Québec's large above-ground transmission and distribution system was considered to be exposed to natural disasters, although the cost of undergrounding the grid was prohibitive.[19]

The technology utilized on Hydro-Québec TransÉnergie grid also came under fire from critics. It is claimed that this technology, used to improve performance, safety, and reliability, made people in Quebec over-dependent on the power grid for their energy needs, since electricity, especially hydroelectric power, makes up over 40% of Quebec's energy supply.[75] This dependence, evidenced by the fact Ontario farmers had more backup generators than farmers in Quebec, can increase the severity of the consequences when the grid fails, as it did in January 1998.[19]

Notes
A. ^ Two figures are given for the length of the 735 kV system: 11,422 and 11,527 km (7,097 and 7,163 mi).
B. ^ a b Estimates on the total number of poles and pylons damaged / destroyed by the ice storm vary.
gollark: There is not some law of physics saying Σbad = Σgood or something. Although humans apparently might have this "happiness set point" thing going on.
gollark: Again, do you have objections to our BEE eugenics machine?
gollark: ...
gollark: You can, in general, reduce total badness. If we eliminated all cancer, say, this would probably lead to net happiness increase.
gollark: That's one of those stupid "balance"y proverbs.

References
General
  • Hyman, Leonard S. (1988). America's Electric Utilities: Past, Present and Future (5 ed.). ISBN 978-0-910325-25-7.
Specific
  1. "Hydro-Québec TransÉnergie". Retrieved 5 March 2016.
  2. Bolduc, André. "Hydro-Québec". The Canadian Encyclopedia. Retrieved 2016-03-05.
  3. Sood, Vijay K. (Spring 2006). "IEEE Milestone : 40th Anniversary of 735 kV Transmission System" (PDF). IEEE Canadian Review: 6–7. Retrieved 2009-03-14.CS1 maint: ref=harv (link)
  4. Sood, Vijay K. (2005-12-13). "IEEE Milestone: 40th Anniversary of 735 kV Transmission System" (PDF). Institute of Electrical and Electronics Engineers. Retrieved 2008-01-10.
  5. "The James Bay Transmission System". Hydro-Québec. Archived from the original on December 21, 2007. Retrieved 2008-01-11.
  6. "Hydro-Québec (1962): historical context, economic impact and related links". 2009-02-16. Archived from the original on February 16, 2009. Retrieved 2016-03-06.
  7. "Hydro-Québec Generation Main Page". Hydro-Québec Generation. Retrieved 2008-01-21.
  8. Lemay, Jacques (June 1992). "Hydro-Québec's High-Voltage Interconnections". IEEE Power Engineering Review. 12 (6): 7. doi:10.1109/MPER.1992.138943.
  9. "Geographic Location: The La Grande Complex". Hydro-Québec. Archived from the original on December 20, 2007. Retrieved 2008-01-21.
  10. "Robert-Bourassa Generating Station". Hydro-Québec. Archived from the original on September 27, 2007. Retrieved 2008-01-21.
  11. "The La Grande Complex". Société d'énergie de la Baie James. Retrieved 2008-01-21.
  12. "Discover our Hydroelectric Facilities". Hydro-Québec Production. Archived from the original on December 31, 2007. Retrieved 2008-01-21.
  13. Government of Quebec (May 1995). Rapport d'enquête et d'audience publique – Projet de centrale hydro-électrique sur la Basse-Côte-Nord (lac Robertson) (in French). Quebec City: Bureau d'audiences publiques sur l'environnement. pp. 33–34. ISBN 978-2-550-12014-8.
  14. Green, Peter. "The History of Churchill Falls: A Brief History". Churchill Falls (Labrador) Corpororation and Institute of Electrical and Electronics Engineers. Retrieved 2008-01-11.
  15. Green, Peter. "Detailed Technical Specifications". Churchill Falls (Labrador) Corporation and Institute of Electrical and Electronics Engineers. Retrieved 2008-01-21.
  16. Hydro-Québec (April 2010). Shaping The Future : Annual Report 2009 (PDF). Montreal. p. 52,92. ISBN 978-2-550-58101-7. ISSN 0702-6706. Archived from the original (PDF) on 2011-06-05. Retrieved 2010-04-08.
  17. "The Development of 735-kV Transmission and Standardization at Hydro-Québec". Standards Council of Canada. 2007-10-16. Archived from the original on 2006-09-24. Retrieved 2008-01-11.
  18. Collins, M.M.C. "Electric-Power Transmission". The Canadian Encyclopedia. Archived from the original on 2006-04-08. Retrieved 2008-01-12.
  19. Burton (1999-01-01). "Glazed over: Canada copes with the ice storm of 1998". Environment: Science and Policy for Sustainable Development. 41: 6–11. doi:10.1080/00139159909604608.
  20. "Power Transmission over Long Distances". Hydro-Québec. Archived from the original on March 14, 2006. Retrieved 2008-01-20.
  21. Hydro-Québec Production (October 2006). "Eastmain 1-A Powerhouse and Rupert Diversion: Area Development" (PDF). Retrieved 2008-01-11.
  22. "Discover Hydro-Québec TransÉnergie and its system: Our System at a Glance". Hydro-Québec TransÉnergie. Archived from the original on 2007-11-02. Retrieved 2008-01-10.
  23. "Milestones:First 735 kV AC Transmission System, 1965". IEEE Global History Network. IEEE. Retrieved 4 August 2011.
  24. HOROWITZ, STANLEY H.; HAROLD T. SEELEY (September 1969). "Relaying the AEP 765-kV System". IEEE Transactions on Power Apparatus and Systems. PAS-88 (9): 1382–1389. Bibcode:1969ITPAS..88.1382H. doi:10.1109/TPAS.1969.292530.
  25. Kelly, Thomas J. (2006-08-23). "Executive Speeches". New York Power Authority. Archived from the original on 2006-09-29. Retrieved 2008-01-11.
  26. "Transmission Questions & Answers: How does the electrical system work?". American Electric Power. Archived from the original on 2008-02-11. Retrieved 2008-01-11.
  27. "Map of the Transmission System" (PDF). Hydro-Québec. Retrieved 2008-01-11.
  28. "Massena Marcy 765 kV Line". Vanderweil Engineers. Archived from the original on October 20, 2007. Retrieved 2008-01-11.
  29. Lings, Raymond; Vernon Chartier; P. Sarma Maruvada (2005-07-15). "Overview of transmission lines above 700 kV". Overview of Transmission Lines Above 700 kV. Inaugural IEEE PES 2005 Conference and Exposition in Africa. pp. 33–43. doi:10.1109/PESAFR.2005.1611782. ISBN 978-0-7803-9326-4.
  30. Hammad, A. E. (January 1992). "Analysis of second harmonic instability for the Chateauguay HVDC/SVC scheme" (PDF). Transactions on Power Delivery. 7 (1): 411. Retrieved 2008-01-23.
  31. "Radisson Substation". Hydro-Québec. Archived from the original on December 21, 2007. Retrieved 2008-01-21.
  32. "Hydro-Québec célèbre le 40e anniversaire de la mise en service de la première ligne à 735 kV" (in French). Hydro-Québec. 2005-11-29. Retrieved 2008-01-20.
  33. Google Earth images.
  34. "James Bay". Purple Lizard Maps. Archived from the original on 2008-01-07. Retrieved 2008-01-11.
  35. "James Bay 4". Purple Lizard Maps. Archived from the original on 2008-01-07. Retrieved 2008-01-11.
  36. "Vegetation Control: Overview". Hydro-Québec. Archived from the original on 2007-12-28. Retrieved 2008-01-11.
  37. "Churchill Falls – Power from the Project". A Scoff an' Scuff's. Archived from the original on 2007-10-30. Retrieved 2008-01-11.
  38. Google Earth elevations.
  39. "Types of Towers". Hydro-Québec. Archived from the original on January 13, 2008. Retrieved 2008-01-20.
  40. Mastrovito, Perry (2001). "Transmission Towers in Winter". Corbis.com. Archived from the original on 2014-04-09. Retrieved 2008-01-11.
  41. Ressmeyer, Roger (1990-10-29). "Transmission Towers for Hydroelectric Power Lines". Corbis.com. Archived from the original on 2014-04-09. Retrieved 2008-01-11.
  42. "Transmission Lines". Our Labrador. Retrieved 2008-01-11.
  43. "Day 3: Radisson & Chisasibi". Purple Lizard Maps. Archived from the original on 2008-01-07. Retrieved 2008-01-19.
  44. Mastrovito, Perry (2001). "Houses Covered in Snow". Corbis.com. Archived from the original on 2014-04-09. Retrieved 2008-01-11.
  45. White, H. Brian (1997-08-01). "Unique Suspension System Conquers Rugged Terrain". Transmission&Distribution World. Retrieved 2008-01-11.
  46. Mastrovito, Perry. "Transmission Tower". Corbis.com. Archived from the original on 2014-04-09. Retrieved 2008-01-12.
  47. "Central Labrador:Virtual Tour Quebec Hwy 389 – Baie Comeau to Labrador City". Retrieved 2008-01-11.
  48. "Photography featuring beautiful bridges, scenic highways and railroads". Massroads.com. Archived from the original on 2011-06-10. Retrieved 2008-01-12.
  49. "Crossings". Hydro-Québec. Archived from the original on January 13, 2008. Retrieved 2008-02-15.
  50. Neilson, Laura. "Ice Storm 1998". The Canadian Encyclopedia. Retrieved 2008-01-12.
  51. Nolen, Stephanie (1998-01-26). "Surviving 1998's Great Ice Storm". The Canadian Encyclopedia. Archived from the original on 2012-11-02. Retrieved 2013-06-26.
  52. "Verglas '98". 1998-03-29. Retrieved 2008-01-12.
  53. Harvey, Stuart L. (1998). "Montreal in the Ice Storm January 1998". Archived from the original on 2007-11-12. Retrieved 2008-01-20.
  54. "The cost of redundancy". energyrisk. Archived from the original on 2006-11-10. Retrieved 2008-01-12.
  55. "TransÉnergie | Hydro-Québec". www.hydroquebec.com. Archived from the original on 2011-06-05. Retrieved 2016-03-05.
  56. "TransÉnergie | Hydro-Québec". www.hydroquebec.com. Retrieved 2016-03-05.
  57. "The HVDC Transmission Quebec – New England". The ABB Group. 2007-02-08. Archived from the original on March 11, 2007. Retrieved 2008-01-11.
  58. "Contracts, All Requirements: Hydro-Québec Interconnection". Massachusetts Municipal Wholesale Electric Company. Archived from the original on November 16, 2007. Retrieved 2008-01-12.
  59. Sueker, Keith H. (2005). "1". Power Electronics Design: A Practitioner's Guide. Elsevier. pp. 8–9. ISBN 978-0-7506-7927-5. Retrieved 2008-01-20.
  60. Northern Pass Transmission (2010). "Route Information". Northern Pass Transmission LLC. Archived from the original on December 20, 2010. Retrieved 2010-10-13.
  61. Alspach, Kyle (2010-10-05). "NStar to build hydro power line". Boston Business Journal. Retrieved 2010-10-12.
  62. Dillon, John (2010-10-08). "New Transmission Line Reaches Milestone". Vermont Public Radio. Retrieved 2010-10-12.
  63. Porter, Louis (19 December 2008). "Utilities plan for N.E. expansion". Rutland Herald. Archived from the original on 15 June 2009. Retrieved 2009-05-09.
  64. "Discover Hydro-Québec TransÉnergie and its system: Features of Our Transmission System". Hydro-Québec TransÉnergie. Archived from the original on 2007-11-02. Retrieved 2008-01-10.
  65. "Hydro-Québec to test internet over power lines". CBC News. 2003-11-24. Retrieved 2008-01-12.
  66. Lerner, Eric J. (August 1995). "Space weather: Page 1". Discover. Retrieved 2008-01-20.
  67. "Scientists probe northern lights from all angles". CBC News. 2005-10-22. Retrieved 2008-01-13.
  68. Bolduc, 2002
  69. "A closer look at a rare situation: Weather Situation". Environment Canada. Archived from the original on June 26, 2006. Retrieved 2008-01-16.
  70. "The worse ice storm in Canadian history?". Environment Canada. 2002-12-18. Archived from the original on July 19, 2006. Retrieved 2008-01-16.
  71. McCready, Jim (2004-10-23). "Ice storm 1998: Lessons learned" (PDF). 6th Canadian Urban Forest Conference. Archived from the original (PDF) on 2006-08-18. Retrieved 2008-01-12.
  72. "DAWG Database 1998: January 1, 1998–December 31, 1998". North American Electric Reliability Corporation. Archived from the original on 2008-01-08. Retrieved 2008-01-12.
  73. "Ice Storm Damage: Powerlines". Archived from the original on 2007-11-16. Retrieved 2008-01-12.
  74. Tucker, Kyle; Asim Haldar (2007-10-04). "Numerical Model Validation and Sensitivity Study of a Transmission-Line Insulator Failure Using Full-Scale Test Data". IEEE Transactions on Power Delivery. 22 (4): 2439. doi:10.1109/TPWRD.2007.899781.
  75. "Failure of Public Utilities: Risk Management and Insurance: Pages 5–7" (PDF). Munich Re. 2003. Retrieved 2008-01-10.
  76. Statistics Canada, The St. Lawrence River Valley 1998 Ice Storm: Maps and Facts (Ottawa, 1998); and Ontario Hydro, The State of the Power Transmission Network, 1998.
  77. Banerjee, Sidhartha (2008-01-03). "Chilling memories of 1998 ice storm that battered Quebec, Ontario, Maritimes". The Canadian Press. Archived from the original on 2011-05-18. Retrieved 2008-01-20.
  78. Fitzpatrick, Meagan (2008-01-04). "Recollections of 1998's Great Ice Storm still bring shivers". National Post and CanWest News Service. Archived from the original on 2008-01-06. Retrieved 2008-01-21.
  79. Swiss Reinsurance Company Canada, Inside an Ice Storm (Toronto, 1998).
  80. Canadian Broadcasting Corporation ,Group claims responsibility for hydro tower bomb, 6 December 2004
  81. Earth Liberation: "Bomb Attack On a Hydro-Quebec Tower", December 6, 2004 (from Google cache).
  82. Report on the State of the Power System, submitted to the ministre d'etat des ressources naturelles du Quebec, 21 January 1998.

This article is issued from Wikipedia. The text is licensed under Creative Commons - Attribution - Sharealike. Additional terms may apply for the media files.