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Erie Shores Wind Farm monthly output over a two year period

Intermittent energy source is a term usually used to refer to some sources of renewable energy, such as wind and solar, (but not to geothermal generated electricity or hydroelectricity), because these sources of electric power generation may be uncontrollably variable or more intermittent than conventional power sources in normal operational conditions. This term implies that conventional sources are not intermittent which is not the case - conventional sources are intermittent but in a different way - to the extent that they cannot be relied on 100% and therefore means have to also be provided to deal with their intermittency. For example this can be the sudden failure of one or more large power plants, e.g. 2009 Sayano-Shushenskaya hydro accident or UK National Grid Sizewell - Longannet Blackout or disruption of connections. Mitigations for these conventional sources' intermittency include: multiplication of sources, back up, fast acting load management, diesel generators [1](see Control of the National Grid section: Diesel generators in the National Grid Reserve Service. ) fast acting operating reserves, and interconnection with other systems; these mitigations can be applied to unconventional intermittent sources such as wind energy.

Paradoxically, for very large penetrations of the most intermittent source, wind energy, such sources when taken together become highly reliable, and whilst the aggregate output can change as weather changes, this is highly predictable and relatively slow, and becomes much more reliable than say a single large power station which can (and do) fail suddenly and unpredictably.[citation needed]

Technological solutions to deal with large scale wind energy type intermittency already exist and studies by academics and grid operators indicate that the cost of compensating for intermittency is expected to be low even at levels of penetration substantially higher than those prevailing today.[2][3] Large, distributed power grids are better able to deal with high levels of penetration than small, isolated grids. For a hypothetical European-wide power grid, - ( European super grid] analysis has shown that for example wind energy penetration levels as high as 70% are viable,[4] and that the cost of the extra transmission lines would be only around 10% of the turbine cost, yielding power at around present day prices.[5] Smaller grids may be less tolerant to high levels of penetration.[6][7]

Matching power demand to supply is not a problem specific to intermittent power sources. Existing power grids already contain elements of uncertainty including sudden and large changes in demand and unforeseen power plant failures. Though power grids are already designed to have some capacity in excess of projected peak demand to deal with these problems, significant upgrades may be required to accommodate large amounts of intermittent power. But again, large amounts of large inflexible plant (nuclear, supercritical coal, coal plus CCS) will also require grid upgrades and increased interconnection or incur financial costs - ie the French nuclear programme necessitated its 2 GW HV link to UK, and increased imports and exports to neighbouring countries.[6] The International Energy Agency (IEA) states: "In the case of wind power, operational reserve is the additional generating reserve needed to ensure that differences between forecast and actual volumes of generation and demand can be met. Again, it has to be noted that already significant amounts of this reserve are operating on the grid due to the general safety and quality demands of the grid. Wind imposes additional demands only inasmuch as it increases variability and unpredictability. However, these factors are nothing completely new to system operators. By adding another variable, wind power changes the degree of uncertainty, but not the kind..."[8]

The US Federal Energy Regulatory Commission (FERC) Chairman Jon Wellinghoff has stated that “baseload capacity is going to become an anachronism” and that no new nuclear or coal plants may ever be needed in the United States implying that his organization does not see intermittency as an issue.[9][10]

At present, the penetration of intermittent renewables in most power grids is low, but wind for example provides nearly 20% of the electricity generated in Denmark (where plans are underway to increase this substantially) [11][12] 11% in Spain and Portugal,[13] 9% in the Republic of Ireland,[13] and 7% in Germany.[14] The use of small amounts of intermittent power has little effect on grid operations. Using larger amounts of intermittent power may require upgrades or even a redesign of the grid infrastructure.[6][15] However, it should be borne in mind that large amounts of large inflexible plant, such as nuclear or supercritical coal or coal plant equipped with CCS will also require significant grid upgrades to deal with their inflexibility.



Several key terms are useful for understanding the issue of intermittent power sources. These terms are not standardized, and variations may be used. Most of these terms also apply to traditional power plants.

  • Intermittency can mean the extent to which a power source is unintentionally stopped or unavailable, but intermittency is frequently used as though it were synonymous with variability.[16][17]
  • Variability is the extent to which a power source may exhibit undesired or uncontrolled changes in output.[16]
  • Dispatchability or maneuverability is the ability of a given power source to increase and/or decrease output quickly on demand. The concept is distinct from intermittency; maneuverability is one of several ways grid operators match output (supply) to system demand.[17]
  • Nominal or nameplate capacity, or maximum effect refers to the normal maximum output of a generating source. This is the most common number used and is typically expressed in megawatts (MW).
  • Capacity factor, average capacity factor, or load factor is the average expected output of a generator, usually over an annual period. Expressed as a percentage of the nameplate capacity or in decimal form (e.g. 30% or 0.30).
  • Capacity credit: generally, the amount of output from a power source that may be statistically relied upon, expressed as a percentage.[18]
  • Penetration or peak penetration refers to the nominal capacity of a power source divided by peak demand in the system grid, expressed as a percentage. Penetration may also be used to refer to the amount of energy generated as a percentage of annual consumption.[19]
  • Reliability in this context means how certain a grid operator can be about the future output or a power source such as a series of wind farms or solar power stations. Thus the solar output shown in the chart below, whilst intermittent, is highly reliable. Similarly, but in a different way, wheres a single 1.2 GW power station can suddenly fail[20], requiring specific ameliorating measures, the output of the equivalent number of wind turbines, (about 250 ) cannot all fail simultaneously and instantaneously.

Intermittency of various power sources


General Problems

Solar output is inherently intermittent, both daily and seasonally, though highly predictable.

While the term "intermittent power sources" is typically used to mean renewables that exhibit inherent intermittency - such as solar at night and wind power when the wind is not blowing - intermittent losses of various power sources can be caused by a number of factors, including:

  • Inherent intermittency of the power type
  • Operator error
  • Planned outages
  • Unplanned outages
  • Component failures
  • Design flaws
  • Grid disconnects
  • Natural disasters
  • Terrorism
  • Fuel pricing/availability

Some factors may result in partial losses, and others may cause the loss of the generating capacity of one or more entire plants.

Solar energy

Seasonal variation of the output of the solar panels at AT&T park in San Francisco.

Intermittency inherently affects solar energy, as the production of electricity from solar sources depends on the amount of light energy in a given location. Solar output varies throughout the day and through the seasons, and is affected by cloud cover. These factors are fairly predictable, and some solar thermal systems make use of heat storage to produce power when the sun is not shining.

The extent to which the intermittency of solar-generated electricity is an issue will depend to some extent on the degree to which the generation profile of solar corresponds to demand. For example, solar thermal power plants such as Nevada Solar One are somewhat matched to summer peak loads in areas with significant cooling demands, such as the south-western United States. Thermal energy storage systems can improve the degree of match between supply and consumption. The increase in capacity factor of thermal systems does not represent an increase in efficiency, but rather a spreading out of the time over which the system generates power.[24][25][26]

Wind energy

A wind farm in Muppandal, Tamil Nadu, India

Wind-generated power is a variable resource, and the amount of electricity produced at any given point in time by a given plant will depend on wind speeds, air density, and turbine characteristics (among other factors). If wind speed is too low (less than about 2.5m/s) then the wind turbines will not be able to make electricity, and if it is too high (more than about 25m/s) the turbines will have to be shut down to avoid damage. While the output from a single turbine can vary greatly and rapidly as local wind speeds vary, as more turbines are connected over larger and larger areas the average power output becomes less variable.[8]

  • Intermittence: A single wind turbine is highly intermittent. Theoretical arguments often claim that a large wind farm spread over a geographically diverse area will as a whole rarely stop producing power altogether,[27] however this is in contradiction to the observed variability in total power output of wind turbines installed in Ireland and Denmark.[28][29]
  • Capacity Factor: Wind power typically has a capacity factor of 20-40%.[21][30]
  • Dispatchability: Wind power is "highly non-dispatchable".[31]
  • Capacity Credit: At low levels of penetration, the capacity credit of wind is about the same as the capacity factor. As the concentration of wind power on the grid rises, the capacity credit percentage drops.[30][32]
  • Variability: Site dependent. Sea breezes are much more constant than land breezes.[8]
  • Reliability: A wind farm is highly reliable (although highly intermittent). That is, the output at any given time will only vary gradually due to falling wind speeds or storms (the latter necessitating shut downs). A typical wind farm is unlikely to have to shut down in less than half an hour at the extreme, whereas an equivalent sized power station can fail totally instantaneously and without warning. The total shut down of a wind farm is highly predictable via weather forecasting.

According to a study of wind in the United States, ten or more widely-separated wind farms connected through the grid could be relied upon for from 33 to 47% of their average output (15–20% of nominal capacity) as reliable, baseload power, as long as minimum criteria are met for wind speed and turbine height.[33][34]

Because wind power is generated by large numbers of small generators, individual failures do not have large impacts on power grids. This feature of wind has been referred to as resiliency.[35]

Wind power is affected by air temperature because colder air is more dense and therefore more effective at producing wind power. As a result, wind power is affected seasonally (more output in winter than summer) and by daily temperature variations. During the 2006 California heat storm output from wind power in California significantly decreased to an average of 4% of capacity for 7 days.[36] A similar result was seen during the 2003 European heat wave, when the output of wind power in France, Germany, and Spain fell below 10% during peak demand times.[37]

5 days of hourly output of five wind farms in Ontario

According to an article in EnergyPulse, "the development and expansion of well-functioning day-ahead and real time markets will provide an effective means of dealing with the variability of wind generation." [38]


A November 2006 analysis found that "wind power may be able to cover more than 50% of the Danish electricity consumption in 2025" under conditions of high oil prices and higher costs for CO2 allowances. [39] However, Denmark has an advantageous power portfolio that includes ample supply of hydroelectric power to offset wind. Most locations do not have this advantage.

In the UK academic commentators such as Graham Sinden, of Oxford University argue that this issue of capacity credit is a "red herring" in that the value of wind generation is largely due to the value of displaced fuel, not any perceived capacity credit - it being well understood by the wind energy proponents that conventional capacity will be retained to "fill in" during periods of low or no wind.[40][41]

Capacity credit, fuel saving and need for extra back up

Many commentators concentrate on whether or not wind has any "capacity credit" without defining what they mean by this and its relevance. Wind does have a capacity credit, using a widely accepted and meaningful definition, equal to about 20% of its rated output (but this figure varies depending on actual circumstances). This means that reserve capacity on a system equal in MW to 20% of added wind could be retired when such wind is added without affecting system security or robustness. But the main value of wind, (in the UK, 5 times the capacity credit value[42]) is its fuel and CO2 savings. Wind does not require any extra back up, as is often wrongly claimed, since it uses the existing power stations which are already built, as back up, and which are started up during low wind periods, just as they are started up now, during the non availability of other conventional plant. More spinning reserve, of existing plant, is required, but this again is already built and has a low cost comparatively. See [43][44]


Power output of a pumped-storage plant. Green areas show excess power being stored, and red areas show power being given back when needed.

Hydroelectric power is usually extremely dispatchable and more reliable than other renewable energy sources. Many dams can provide hundreds of megawatts within seconds of demand (see Ffestiniog power station). The exact nature of the power availability depends on the type of plant.

In run-of-the-river hydroelectricity, power availability is highly dependent on the uncontrollable flow of the river.[8]

In conventional hydroelectric plants, there is a reservoir and a one-way generator. The water level of the reservoir can be adjusted frequently to meet changing demand throughout the day by running the generator when demand is high and not running it when demand is low.

Pumped-storage hydroelectricity can make an even more significant contribution to peaking ability of the grid. These just move water between reservoirs and are powered by power from the grid when demand is low and put power back into the grid when demand is high. There also exist combined pump-storage plants that use river flow as well as extra pumping when demand is low, such as the 240 MW Lewiston Pump-Generating Plant.[8]

Direct pumped-storage does not contribute any net generation to the grid, in fact, it increases the fuel used by other power plants because there is inefficiency in the turbine/generator. The economic benefit of pumped-storage plants lies only in increasing the capacity of the grid. This type of plant works well on a grid with many nuclear or renewable energy plants because the fuel is very cheap or essentially free, so it costs very little to keep them running at high power during the night when demand is low. Both pump-storage plants and natural flow hydro plants can help allow for intermittency of other plants by running at higher capacity for short times, but assistance is limited by the total capacity of the hydroelectric plant.

Conventional power stations

Once a conventional power station has come offline it may stay that way for more than a week.[45]

Conventional power plants (as well as nuclear plants) use water for cooling, and water shortages during hot summer months has occasionally resulted in periods when output has had to be curtailed, notably in France in 2006.[46]

Conventional power plant failures can remove large amounts of capacity from the grid suddenly, resulting in blackouts.[47]

  • Capacity factor: Base load coal plant 70-90%[21]

Gas-fired generation

Gas-fired plants are typically very reliable and dispatchable. These kinds of plants also often have the ability to quickly vary their output to adjust to the frequent jumps and changes in consumer demand. Thus these are very good as peaking units. These benefits are weighted against the high price of gas when deployed in the grid.[48]

  • Capacity factor: about 60%.[21]

Nuclear power

Seasonal variation in total nuclear power delivered to the grid in the United States compared to the demand cycle.

Nuclear power is considered a base load power source, in that its output is nearly constant and other types of plants are adjusted with changes in demand. This is done because output changes can only be made in small increments, and because of small fuel costs - there is little marginal cost between running at a low power and a high power, therefore it is cheapest for the system to run the nuclear plants at high power. Every year or two (depending on the plant), the plant must be shut down for planned outages for about a month. This is typically done in the spring or autumn (fall) when electricity demand is lower, as such, on a national scale power output from nuclear increases corresponding with demand during the peak summer and winter months. This change in output commonly occurs on a yearly scale, it is rare that nuclear power plants adjust their power output to correspond with demand on a daily basis, which would be much more likely to happen in countries where over 50% of their power comes from nuclear (such as France).

  • Intermittence: Unplanned outages worldwide caused power losses varying from 3.1% and 1.4% of capacity between 1995 and 2005. Over that same period reactors worldwide encountered an average of 1.1 to 0.6 SCRAMs per 7,000 hours critical (about a year of operation.)[49] An automatic SCRAM is a protective measure that shuts the reactor down suddenly for safety reasons.
  • Capacity factor: U.S. average 92%.[21] Worldwide average varied between about 81% to 87% between 1995 and 2005.[49]

In the UK one of the key criteria for determining the amount of required spinning reserve is the possible loss of Sizewell B, a 1.2GW nuclear power plant.[50] At one point in the fall of 2007, out of 16 nuclear power stations in the UK, 7 were offline due to a combination of planned and unplanned outages.[51]

Diesel engine generation

Small high speed diesels are very commonly used within large power grids throughout North America and Europe. France uses about 5 GW of such diesels to cover the intermittency of their nuclear stations; these are all in private hands - at small scales factories and the like - with their usage being triggered semi-randomly by a special tariff - EJP [52]- which encourages these users to start their diesels.

In USA and UK these diesels have usually been purchased for other reasons e.g. for emergency standby, in water works, hotels, hospitals, etc. and in some cases for electricity substations - e.g. Cuyahoga Falls, USA (10 x 1.6 MW Caterpillar) and Tregarron Mid Wales UK (3 x 1.6 MW Caterpillar), but can be readily used to automatically synchronize and feed into the grid.

In the UK 500 MW of such plant is routinely started within a few minutes; this is perfectly acceptable to the engines' service life in a scheme operated by National Grid called National Grid Reserve Service. It has been established that there is 20 GW of such diesel plant in the UK and it has been pointed out that there is no technical reason why this quantity could not be brought into the Reserve Service scheme to assist handling very rapid changes in renewable output, whilst conventional plant is started or indeed stopped.[40][53] [54]

Compensating for variability

All sources of electrical power have some degree of unpredictability, and demand patterns routinely drive large swings in the amount of electricity that suppliers feed into the grid. Wherever possible, grid operations procedures are designed to match supply with demand at high levels of reliability, and the tools to influence supply and demand are well-developed. The introduction of large amounts of highly variable power generation may require changes to existing procedures and additional investments.

Operational reserve

All managed grids already have existing operational and "spinning" reserve to compensate for existing uncertainties in the power grid. The addition of intermittent resources such as wind does not require 100% "back-up" because operating reserves and balancing requirements are calculated on a system-wide basis, and not dedicated to a specific generating plant.

  • Some coal, gas, or hydro power plants are partially loaded and then controlled to change as demand changes or to replace rapidly lost generation. The ability to change as demand changes is termed "response." The ability to quickly replace lost generation, typically within timescales of 30 seconds to 30 minutes, is termed "spinning reserve."
  • Generally thermal plants running as peaking plants will be less efficient than if they were running as base load.
  • Hydroelectric facilities with storage capacity (such as the traditional dam configuration) may be operated as base load or peaking plants.
  • In practice, as the power output from wind varies, partially loaded conventional plants, which are already present to provide response and reserve, adjust their output to compensate.
  • While low penetrations of intermittent power may utilize existing levels of response and spinning reserve, the larger overall variations at higher penetrations levels will require additional reserves or other means of compensation.

Demand reduction or increase

  • Demand response refers to the use of communication and switching devices which can release deferrable loads quickly, or absorb additional energy to correct supply/demand imbalances. Incentives have been widely created in the American, British and French systems for the use of these systems, such as favorable rates or capital cost assistance, encouraging consumers with large loads to take them off line or to start diesels whenever there is a shortage of capacity, or conversely to increase load when there is a surplus.
  • Load Control allows the power company to turn loads off remotely if insufficient power is available. In France large users such as CERN cut power usage as required by the System Operator - EDF under the encouragement of the EJP tarrif[55][56].
  • Energy demand management refers to incentives to adjust use of electricity, such as higher rates during peak hours.
  • Real-time variable electricity pricing can encourage users to adjust usage to take advantage of periods when power is cheaply available and avoid periods when it is more scarce and expensive.[57]
  • Instantaneous demand reduction. Most large systems also have a category of loads which instantly disconnect when there is a generation shortage, under some mutually beneficial contract. This can give instant load reductions (or increases). See National Grid Reserve Service
  • Diesel generators, originally or primarily installed for emergency power supply are often also connected to the National Grid in the UK to help deal with short term demand supply mismatches.[58]

Storage and demand loading

At times of low or falling demand where wind output may be high or increasing, grid stability may require lowering the output of various generating sources or even increasing demand, possibly by using energy storage to time-shift output to times of higher demand. Such mechanisms can include:

  • Storage of electrical energy results in some lost energy because storage and retrieval are not perfectly efficient.
  • Storage may require substantial capital investment and space for storage facilities.
  • Pumped storage hydropower is the most prevalent existing technology used, and can substantially improve the economics of wind power. The availability of hydropower sites suitable for storage will vary from grid to grid. Typical round trip efficiency is 80%.[8][59] See also: Pumped-storage hydroelectricity
  • Thermal energy storage stores heat or ice (or a similarly cold material). Stored heat can be used directly for heating needs or converted into electricity. Stored ice can be used as a source of air-conditioning during periods of high demand.
  • Various other potential applications are being considered, such as charging plug-in electric vehicles during periods of low demand and high production; such technologies are not widely used at this time.
  • Hydrogen can be created through electrolysis and stored for later use. NREL found that a kilogram of hydrogen (roughly equivalent to a gallon of gasoline) could be produced for between $5.55 in the near term and $2.27 in the long term.[60]
  • Rechargeable flow batteries can serve as a large capacity, rapid-response storage medium.[17] Main article: Flow batteries
  • Some loads such as desalination plants and electric boilers, are able to store their output (water and heat.) These "opportunistic loads" are able to take advantage of "burst electricity" when it is available.

Geographic diversity

The variability of production from a single wind turbine can be high. Combining any additional number of turbines (for example, in a wind farm) results in lower statistical variation, as long as the correlation between the output of each turbine is imperfect, and the correlations are always imperfect due to the distance between each turbine. Similarly, geographically distant wind turbines or wind farms have lower correlations, reducing overall variability. Since wind power is dependent on weather systems, there is a limit to the benefit of this geographic diversity for any power system.

Multiple wind farms spread over a wide geographic area and gridded together produce power more constantly and with less variability than smaller installations. Wind output can be predicted with some degree of confidence using weather forecasts, especially from large numbers of turbines/farms. The ability to predict wind output is expected to increase over time as data is collected, especially from newer facilities.

Complementary power sources and matching demand

  • Electricity produced from solar energy could be a counter balance to the fluctuating supplies generated from wind. In some locations, it tends to be windier at night and during cloudy or stormy weather, so there is likely to be more sunshine when there is less wind.[61]
  • In some locations, electricity demand may have a high correlation with wind output, particularly in locations where cold temperatures drive electric consumption (as cold air is denser and carries more energy).
  • The allowable penetration may be further increased by increasing the amount of part-loaded generation available. Systems with existing high levels of hydroelectric generation may be able to incorporate substantial amounts of wind, although high hydro penetration may indicate that hydro is already a low-cost source of electricity; Norway, Quebec, and Manitoba all have high levels of existing hydroelectric generation (Quebec produces over 90% of its electricity from hydropower, and the local utility, Hydro-Québec, is the largest single hydropower producer in the world). The US Pacific Northwest has been identified as another region where wind energy is complemented well by existing hydropower, and there were "no fundamental technical barriers" to integrating up to 6,000 MW of wind capacity.[62] Storage capacity in hydropower facilities will be limited by size of reservoir, and environmental and other considerations.
  • The Institute for Solar Energy Supply Technology of the University of Kassel, Germany pilot-tested a combined power plant linking solar, wind, biogas and hydrostorage to provide load-following power around the clock, entirely from renewable sources.[63]

Export & import arrangements with neighboring systems

  • It is often feasible to export energy to neighboring grids at times of surplus, and import energy when needed. This practice is common in Western Europe and North America.
  • Integration with other grids can lower the effective concentration of variable power. Denmark's 44% penetration, in the context of the German/Dutch/Scandinavian grids with which it has interconnections, is considerably lower as a proportion of the total system. This effect is diminished if more neighboring grids also have high penetration levels of variable power.
  • Integration of grids may decrease the overall variability of both supply and demand by increasing geographical diversity.
  • Methods of compensating for power variability in one grid, such as peaking-plants or pumped-storage hydro-electricity, may be taken advantage of by importing variable power from another grid that is short on such capabilities..
  • The capacity of power transmission infrastructure may have to be substantially upgraded to support export/import plans.
  • Some energy is lost in transmission.
  • The economic value of exporting variable power depends in part on the ability of the exporting grid to provide the importing grid with useful power at useful times for an attractive price.


Penetration refers to the nominal capacity of a power source divided by peak demand in the system grid, expressed as a percentage. Penetration may also be used to refer to the amount of energy generated as a percentage of annual consumption.[19]

  • As penetration increases, the variations in power produced for the grid become larger and the costs and complexity of compensating for these variations increases.
  • Large, geographically distributed networks may accept a higher penetration of wind than small networks because fluctuations in supply and demand across the entire grid can be averaged out.
  • Power grids with significant amounts pumped storage, hydropower or other peaking power plants such as natural gas-fired power plants are more inherently capable of accommodating fluctuations from intermittent power.[64]
  • If an intermittent source produces more power than can be used, stored, or exported at that time, then that excess power will be lost.
  • Wind power generation tends to be higher in the winter and at night (due to higher air density), so the appropriateness of wind power in high concentrations may crucially depend on the prevalence of air conditioning in a given jurisdiction. Wind power may be weakest in the hot summer months, and particularly during the day when air conditioning demand is highest. Conversely, systems where heat is electrical may be well-suited to higher penetration of wind power.
  • Isolated, relatively small systems with only a few wind plants may only be stable and economic with a lower fraction of wind energy (e.g. Ireland), although mixed wind/diesel systems have been used in isolated communities with success at relatively high penetration levels.[65]

The maximum proportion of intermittent power allowable in a power system will thus depend on many factors, including the size of the system, the attainable geographical diversity, the ability of the system to transmit power to where it is needed, storage capabilities, demand control capabilities, the conventional plant mix (coal, gas, nuclear, hydroelectric) and seasonal load factors (heating in winter, air-conditioning in summer) and their statistical correlation with power output.

There is no generally accepted maximum level of penetration, as each system's capacity to compensate for intermittency differs, and the systems themselves will change over time. Discussion of acceptable or unacceptable penetration figures should be treated and used with caution, as the relevance or significance will be highly dependent on local factors, grid structure and management, and existing generation capacity.

For most systems worldwide, existing penetration levels are significantly lower than practical or theoretical maximums; for example, a UK study found that "it is clear that intermittent generation need not compromise electricity system reliability at any level of penetration foreseeable in Britain over the next 20 years, although it may increase costs."[66] As of 2006, Denmark has more than 40% penetration and at least two other countries (Portugal and Germany) have penetration levels (nominal to peak demand) of more than 20%.

Maximum penetration limits

There is no generally accepted maximum penetration of wind energy that would be feasible in any given grid. Rather, economic efficiency and cost considerations are more likely to dominate as critical factors; technical solutions may allow higher penetration levels to be considered in future, particularly if cost considerations are secondary.

High penetration scenarios may be feasible in certain circumstances:

  • Power generation for periods of little or no wind generation can be provided by retaining the existing power stations. The cost of using existing power stations for this purpose may be low since fuel costs dominate the operating costs. The actual cost of paying to keep a power station idle, but usable at short notice, may be estimated from published spark spreads and dark spreads. As existing traditional plant ages, the cost of replacing or refurbishing these facilities will become part of the cost of high-penetration wind if they are used only to provide operational reserve.
  • Automatic load shedding of large industrial loads and its subsequent automatic reconnection is established technology and used in the UK and US, and known as Frequency Service contractors in the UK. Several GW are switched off and on each month in the UK in this way. Reserve Service contractors offer fast response gas turbines and even faster diesels in the UK, France and US to control grid stability.
  • In a close-to-100% wind scenario, surplus wind power can be allowed for by increasing the levels of the existing Reserve and Frequency Service schemes and by extending the scheme to domestic-sized loads. Energy can be stored by advancing deferrable domestic loads such as storage heaters, water heaters, fridge motors, or even hydrogen production, and load can be shed by turning such equipment off.
  • Alternatively or additionally, power can be exported to neighboring grids and re-imported later. HVDC cables are efficient with 3% loss per 1000 km and may be inexpensive in certain circumstances. For example an 8 GW link from UK to France would cost about £1 billion using high-voltage direct current cables. Under such scenarios, the amount of transmission capacity required may be many times higher than currently available.

Penetration Studies

Studies have been conducted to assess the viability of specific penetration levels in specific energy markets.

European super grid

A series of detailed modelling studies by Dr. Gregor Czisch, which looked at the European wide adoption of renewable energy and interlinking power grids the European super grid using HVDC cables, indicates that the entire European power usage could come from renewables, with 70% total energy from wind at the same sort of costs or lower than at present.[7] This proposed large European power grid has been called a "super grid." [67][68]

The model deals with intermittent power issues by using base-load renewables such as hydroelectric and biomass for a substantial portion of the remaining 30% and by heavy use of HVDC to shift power from windy areas to non-windy areas. The report states that "electricity transport proves to be one of the keys to an economical electricity supply" and underscores the importance of "international co-operation in the field of renewable energy use [and] transmission." [7][69][70]

Dr. Czisch described the concept in an interview, saying "For example, if we look at wind energy in Europe. We have a winter wind region where the maximum production is in winter and in the Sahara region in northern Africa the highest wind production is in the summer and if you combine both, you come quite close to the needs of the people living in the whole area - let's say from northern Russia down to the southern part of the Sahara." [71]

Grid study in Ireland

A study of the grid in Ireland indicates that it would be feasible to accommodate 42% (of demand) renewables in the electricity mix.[72] This acceptable level of renewable penetration was found in what the study called Scenario 5, provided 47% of electrical capacity (different from demand) with the following mix of renewable energies:

  • 6,000 MW wind
  • 360 MW base load renewables
  • 285 MW additional variable renewables (other intermittent sources)

The study cautions that various assumptions were made that "may have understated dispatch restrictions, resulting in an underestimation of operational costs, required wind curtailment, and CO2 emissions" and that "The limitations of the study may overstate the technical feasibility of the portfolios analyzed..."

Scenario 6, which proposed renewables providing 59% of electrical capacity and 54% of demand had problems. Scenario 6 proposed the following mix of renewable energies:

  • 8,000 MW wind
  • 392 MW base load renewables
  • 1,685 MW additional variable renewables (other intermittent sources)

The study found that for Scenario 6, "a significant number of hours characterized by extreme system situations occurred where load and reserve requirements could not be met. The results of the network study indicated that for such extreme renewable penetration scenarios, a system re-design is required, rather than a reinforcement exercise." The study declined to analyze the cost effectiveness of the required changes because "determination of costs and benefits had become extremely dependent on the assumptions made" and this uncertainty would have impacted the robustness of the results.[6]


A study published in October, 2006, by the Ontario Independent Electric System Operator (IESO) found that "there would be minimal system operation impacts for levels of wind capacity up to 5,000 MW," which corresponds to a peak penetration of 17%[73]

Economic impacts of variability

Estimates of the cost of wind energy may include estimates of the "external" costs of wind variability, or be limited to the cost of production. All electrical plant has costs that are separate from the cost of production, including, for example, the cost of any necessary transmission capacity or reserve capacity in case of loss of generating capacity. Many types of generation, particularly fossil fuel derived, will also have cost externalities such as pollution, greenhouse gas emission, and habitat destruction which are generally not directly accounted for. The magnitude of the economic impacts is debated and will vary by location, but is expected to rise with higher penetration levels. At low penetration levels, costs such as operating reserve and balancing costs are believed to be insignificant.

Intermittency may introduce additional costs that are distinct from or of a different magnitude than for traditional generation types. These may include:

  • Transmission capacity: transmission capacity may be more expensive than for nuclear and coal generating capacity due to lower load factors. Transmission capacity will generally be sized to projected peak output, but average capacity for wind will be significantly lower, raising cost per unit of energy actually transmitted. However transmission costs are a low fraction of total energy costs.[74]
  • Additional operating reserve: if additional wind does not correspond to demand patterns, additional operating reserve may be required compared to other generating types, however this does not result in higher capital costs for additional plants since this is merely existing plants running at low output - spinning reserve. Contrary to statements that all wind must be backed by an equal amount of "back-up capacity", intermittent generators contribute to base capacity "as long as there is some probability of output during peak periods." Back-up capacity is not attributed to individual generators, as back-up or operating reserve "only have meaning at the system level."[75]
  • Balancing costs: to maintain grid stability, some additional costs may be incurred for balancing of load with demand. The ability of the grid to balance supply with demand will depend on the rate of change of the amount of energy produced (by wind, for example) and the ability of other sources to ramp production up or scale production down. Balancing costs have generally been found to be low.
  • Storage, export and load management: at high penetrations (more than 30%),[citation needed] solutions (described below) for dealing with high output of wind during periods of low demand may be required. These may require additional capital expenditures, or result in lower marginal income for wind producers.

Analyses of costs

Studies have been performed to determine the costs of variability. The British Wind Energy Association states:

A review of integration studies, worldwide, suggests that the additional costs of integrating wind are around £2/MWh with 10% wind, rising to £3/MWh with 20% wind.[50]

Colorado - Separate reports by Xcel and UCS

An official at Xcel Energy claimed that at 20 percent penetration, additional standby generators to compensate for wind in Colorado would cost $8 per MWh, adding between 13% and 16% to the $50–$60 cost per MWh of wind energy.[76]

The Union of Concerned Scientists conducted a study of the costs to increase the renewable penetration in Colorado to 10% and found that for an average residential bill "customers of municipal utilities and rural electric cooperatives that opt out of the solar energy requirement" would save 4 cents per month, but that for Xcel Energy customers there would be additional cost of about 10 cents per month. Total impact on all consumers would be $4.5 million or 0.01% over two decades.[3][77]

UK Studies

National Grid study of 10% renewables by 2010

A detailed study for UK National Grid (a private power company) states "We have estimated that for the case with 8,000 MW of wind needed to meet the 10% renewables target for 2010, balancing costs can be expected to increase by around £2 per MWh of wind production. This would represent an additional £40million per annum, just over 10% of existing annual balancing costs." [78][79]

National Grid study of 40% renewables

In evidence to the UK House of Lords Economic Affairs Select Committee, National Grid have quoted estimates of balancing costs for 40% wind and these lie in the range £500-1000M per annum. "These balancing costs represent an additional £6 to £12 per annum on average consumer electricity bill of around £390."[2]

National Grid notes that "increasing levels of such renewable generation on the system would increase the costs of balancing the system and managing system frequency." [79]

Carbon Trust & DTI study of 10% by 2010

A 2003 report by Carbon Trust and the UK Department of Trade and Industry (DTI) found that the costs for reinforcement and new build of transmission and distribution systems to support 10% renewable electricity in the UK by 2010 would be £1.6 to £2.4 billion.

The study classified "Intermittency" as "Not a significant issue" for the 2010 target.[15]

Carbon Trust & DTI study of 20% by 2020

The same 2003 study found that achieving 20% renewable electricity in the UK by 2020 would cost £3.2bn to £4.5bn in transmission and distribution system construction and reinforcement.

The study classified "Intermittency" as a "Significant Issue" for the 2020 target.[15]


Minnesota study on wind penetration levels and found that "total integration operating cost for up to 25% wind energy" would be less than $0.0045 per kWh (additional).[80][81]

Intermittency and renewable energy

There are differing views about some sources of renewable energy and intermittency. The World Nuclear Association argues that the sun, wind, tides and waves cannot be controlled to provide directly either continuous base-load power, or peak-load power when it is needed.[82] Proponents of renewable energy use argue that the issue of intermittency of renewables is over-stated, and that practical experience demonstrates this.[83]. In any case, geothermal renewable energy has no intermittency.

Views of critics of high penetration renewable energy use

The World Nuclear Association states that:

Sun, wind, tides and waves cannot be controlled to provide directly either continuous base-load power, or peak-load power when it is needed. In practical terms they are therefore limited to some 10-20% of the capacity of an electricity grid, and cannot directly be applied as economic substitutes for coal or nuclear power, however important they may become in particular areas with favourable conditions.
The fundamental problem, especially for electricity supply, is their variable and diffuse nature. This means either that there must be reliable duplicate sources of electricity, or some means of electricity storage on a large scale. Apart from pumped-storage hydro systems, no such means exist at present and nor are any in sight.
Relatively few places have scope for pumped storage dams close to where the power is needed, and overall efficiency is low. Means of storing large amounts of electricity as such in giant batteries or by other means have not been developed.[82]

On December 10, 2007 Patrick Moore, co-chair of the Clean & Safe Energy Coalition [84] - a pro-nuclear group funded by the Nuclear Energy Institute[85] - wrote:

Greenpeace is deliberately misleading the public into thinking that wind and solar energy, both of which are inherently intermittent and unreliable, can replace baseload power that is continuous and reliable. Only three technologies can produce large amounts of baseload power: fossil fuels, hydroelectric plants and nuclear power. Given that we want to reduce fossil fuels and that potential hydroelectric sites are becoming scarce, nuclear power is the main option... Over the past 10 years, Germany and Denmark have poured billions of taxpayers' euros into wind and solar energy in the vain hope that this would allow them to shut down fossil fuel and nuclear plants. They have not succeeded because every solar panel and every wind turbine must be backed up by reliable power when the sun isn't shining and the wind isn't blowing.[86]

Mr. Moore is a co-founder and former leader of Greenpeace, but he has not been involved with Greenpeace since 1986.[87]

Views of proponents of high penetration renewable energy use

Australian researchers at the University of New South Wales claim to have solved the energy storage problem for solar and wind power with the development of vanadium redox batteries (U.S. patent issued in 1986).

Some renewable electricity sources have identical variability to coal-fired power stations, so they are base-load, and can be integrated into the electricity supply system without any additional back-up. Examples include:

  • Bio-energy, based on the combustion of crops and crop residues, or their gasification followed by combustion of the gas.

Furthermore, supporters argue that the total electricity generated from a large-scale array of dispersed wind farms, located in different wind regimes, cannot be accurately described as intermittent, because it does not start up or switch off instantaneously at irregular intervals.[89] With a small amount of supplementary peak-load plant, which operates infrequently, large-scale distributed wind power can substitute for some base-load power and be equally reliable.[90]

Hydropower can be intermittent and/or dispatchable, depending on the configuration of physical plant. Typical hydroelectric plants in the dam configuration may have substantial storage capacity, and be considered dispatchable. Run of the river hydroelectric generation will typically have limited or no storage capacity, and will be variable on a seasonal or annual basis (dependent on rainfall and snow melt).[8]

Amory Lovins suggests a few basic strategies to deal with these issues:

"The variability of sun, wind and so on, turns out to be a non-problem if you do several sensible things. One is to diversify your renewables by technology, so that weather conditions bad for one kind are good for another. Second, you diversify by site so they're not all subject to the same weather pattern at the same time because they're in the same place. Third, you use standard weather forecasting techniques to forecast wind, sun and rain, and of course hydro operators do this right now. Fourth, you integrate all your resources — supply side and demand side..."[91]

Moreover, efficient energy use and energy conservation measures can reliably reduce demand for base-load and peak-load electricity.[27][88]

Several studies have demonstrated the technical feasibility of integrating intermittent power at levels substantially higher than is common in most countries (from 15-30% penetration),[citation needed] and at least three countries have more than 20% wind penetration.[citation needed] Relatively few changes to large grids are normally required and the associated system costs are moderate[citation needed]. International groups are studying much higher penetrations (30-75%, corresponding to up to 20% of national electricity consumption) and preliminary conclusions are that these levels are also technically feasible.[92] In the UK, one summary of other studies indicated that if assuming that wind power contributed less than 20% of UK power consumption, then the intermittency would cause only moderate cost.[93]

Methods to manage wind power integration range from those that are commonly used at present (e.g. demand management) to potential new technologies for grid energy storage. Improved forecasting can also contribute as the daily and seasonal variations in wind and solar sources are to some extent predictable.

The Pembina Institute and the World Wide Fund for Nature state in the Renewable is Doable plan that resilience is a feature of renewable energy:

Diversity and dispersal also add system security. If one wind turbine fails, the lights won't flicker. If an entire windfarm gets knocked out by a storm, only 40,000 people will lose power. If a single Darlington reactor goes down, 400,000 homes, or key industries, could face instant blackouts. To hedge this extra risk, high premiums have to be paid for decades to ensure large blocks of standby generation.[35]

See also

Further reading

These peer-reviewed papers examine the impacts of intermittency:

Dale, L; Milborrow, D; Slark, R; & Strbac, G, 2003, A shift to wind is not unfeasible (Total Cost Estimates for Large-scale Wind Scenarios in UK), Power UK, no. 109, pp. 17–25.

Farmer, E; Newman, V; & Ashmole, P, Economic and operational implications of a complex of wind-driven power generators on a power system, IEE Proceedings A, 5 edn. vol. 127.

Gross, R; Heptonstall, P; Anderson, D; Green, T; Leach, M; & Skea, J, 2006, The Costs and Impacts of Intermittency. UK Energy Research Centre, London [1]

Gross, R; Heptonstall, P; Leach, M; Anderson, D; Green, T; & Skea, J, 2007, Renewables and the grid: understanding intermittency, Proceedings of ICE, Energy, vol. 160, no. 1, pp. 31–41.

Grubb, M, 1991, The integration of renewable electricity sources, Energy Policy, vol. 19, no. 7, pp. 670–688.

Halliday, J; Lipman, N; Bossanyi, E; & Musgrove, P, 1983, Studies of wind energy integration for the UK national electricity grid, American Wind Energy Association Wind Worksop VI, Minneapolis.

Holttinen, H, 2005, Impact of hourly wind power variations on the system operation in the Nordic countries, Wind energy, vol. 8, no. 2, pp. 197–218.

Ilex & Strbac, G, 2002, Quantifying The System Costs Of Additional Renewables in 2020, DTI, urn 02/1620 [2]

Milligan, M, 2001, A Chronological Reliability Model to Assess Operating Reserve Allocation to Wind Power Plants, National Renewable Energy Laboratory, The 2001 European Wind Energy Conference [3]

Skea, J; Anderson, D; Green, T; Gross, R; Heptonstall, P; & Leach, M, 2008, Intermittent renewable generation and maintaining power system reliability, Generation, Transmission & Distribution, IET, vol. 2, no. 1, pp. 82–89.


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