# Overview

Power plants using renewable fuels (e.g. power production based on biomass) generally allow scheduling of electricity production, as their primary source of energy can be stored and transported. Within an electricity supply system their use can be planned like any gas- or coal power plant. The process of schedule-development in an electricity supply system is called dispatch. Thus the integration of these dispatchable renewable energy plants does not cause significant changes in the system[1].

In contrast to this, wind turbines or wind parks are non-dispatchable sources of electricity production: Wind velocity and the related amount of electricity generated is only predictable by meteorological methods (with a limited certainty), but of course there is no possibility to influence the availability of the renewable resources. Electricity production by wind turbines is determined by the available wind velocity and the electricity supply system has to adapt to the characteristics of wind energy, if the potentials of this renewable resource should be used effectively. Efficient integration of wind energy into an existing power system thus requires an advanced management of the conventional power plant[1]. This article focusses on the effects of wind energy integration on the reliability of an electricity supply system. The Capacity Credit is described as a way to quantify the reliability of electricity generation by wind turbines.

# Wind Variability

The variability of electricity production by wind turbines is generally due to changes in wind speed over time.

The wind variability can be described on several different time scales:

• Variations of wind potentials from year to year
• Seasonal variations of average wind speeds; in Germany average wind velocity during winter months is usually twice as high as the wind speed in the summer[2].
• Changes in weather cause wind variability on the time-scale of weeks and several days;
• Within 24 hours a significant difference of wind speeds between daytime and night can be observed at most sites. Variations during daytime could show characteristic patterns, depending very strongly on climatic conditions of the site,
• Wind speed varies from hour to hour and also from one minute to the next
• Variations on the time-scale of seconds are described as turbulence[3].

The extent of variations on the listed time-scales differs considerably. The largest share of the total variability of wind speed is contributed by variations within 3-5 days, because during this period of time significant changes in weather can occur. Concerning the operation of an electricity supply system, these changes can be regarded as slow. The second major contribution to overall variability is induced by turbulence, which may cause more serious problems for the management of a supply system. If wind turbines are aggregated in a wind park, this has a balancing effect on turbulence effects on electricity production[4][5].

Within the time-frame of 10 minutes to one hour frequency and extent of variations are relatively small. This so-called spectral gap is a very advantegous characteristic of wind speed distribution: If the the variations within this period of time had been considerable, this would have result in larger complications for wind energy integration into the electricity supply system[3]. ►Go to Top

# Variability of Electricity Production

The characteristics of electricity production are influenced to a considerable extent by the chosen turbine type. As the description of these influences requires detailed technical explaination of the turbine types, this article abstracts from these differences. The focus is rather set on the general 'transmission' of wind variability into variability of the electricity production.

Variability in electricity production may be described concerning three main characteristics[6]:

• Full load hours respectively annual energy yield,
• periodical patterns of electricity generation by wind turbines,
• Volatility of electricity generation by wind turbines

Hours of full load is a term describing the number of hours the wind turbines have been operated at their rated capacity during one year. The annual energy yield is usually given in MWh (or GWh). The term 'periodical patterns of electricity generation' describes any patterns in wind variability, which can be observed with regularity irrespective of frequently changes on other time-scales. For example the regular seasonal changes in wind speed distribution cause similar variations in electricity generation[7]. The term volatility is used for changes within small time-frames from minutes to hours.

The 'translation' of wind variability into the variability of electricity generation, fundamentally depends on the following factors[6]:

• Characteristics of the extraction of wind energy by modern wind turbine types
• site selection, geographical distribution of wind turbines
• wind turbine operation: in a wind park (aggregated electricity generation) or as a sole application

The power – extractable by a wind turbine at a certain wind speed – is given by the following function:

${\displaystyle P={\frac {1}{2}}\cdot \rho \cdot A\cdot V^{3}\cdot c_{p}}$

where ρ is used for air density, A indicates the area swept by the turbine rotor, V describes wind velocity and Cp is the power coefficient describing the efficiency of wind energy conversion by the turbine[3]. As electricity production changes proportional to the cube of wind speed, variability of wind speed results in significantly larger variations of electricity generation.

Depending on the design of modern wind turbines, this is only valid for a certain range of wind speed variations:

Very low wind speeds do not contain sufficient power to operate wind turbines. Typically modern wind turbines have a so-called Cut-in-wind speed Vci of 3,5 m/s and reach their maximum power at a rated wind speed Vn. Many turbines have a Vn-value of 15 m/s. Above this wind speed the operation of the wind turbines are regulated by aerodynamic control mechanisms to limit rotor speed and the related output. As a result variations of power output at wind speeds between 15 m/s und 25 m/s are low. The wind velocity 25 m/s (equivalent to wind force 10 Beaufort) is often determined as Cut-out-Wind speed Vco[3][8].

Wind conditions on site of course are the foundation for the expected electricity production and its variability. Besides average wind speed and wind speed distribution of the site, the roughness of the surface is essential for expected wind energy production. Any obstacles like forrests, infrastructure or even fences increase friction of wind on the surface as well as higher turbulence[6].

In many cases wind turbines are integrated into the electricity grid as aggregated wind parks (instead of integrating single wind turbines). Aggregating the output of several wind turbines in a wind park reduces the variability induced into the grid significantly. This effect is based on the spatial distribution of the turbines: If wind turbines are installed distributed over a large area, turbulences affect energy production at the different turbines in an uncorrelated way and variations on a time-scale of seconds are balanced out to a considerable share[3].
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# Impact of Variability in Electricity Production on the Operation of the Electricity Supply System

Integration of wind energy into an electricity supply system means introducing some additional uncertainty. In a system containing only convential power plants (e.g. coal, gas) the main sources of variability are misestimations of electricity demand and power plant outages. For both factors a probability can be assumed and is used in calculation of the necessary reserve capacity, which has to be retained to balance out mismatches between electricity demand and supply[9].
The impact of wind energy integration on the system operation essentialy depends on the policy framework conditions for wind energy in the country. If the policy framework contains a purchase guarantee for electricity generated by wind turbines, wind energy is fed into the grid whenever sufficient wind speeds occur. The impact of grid integration can be described roughly as follows:

As a part of electricity demand is covered by wind energy, the residual demand, which has to be covered by conventional plants, declines. This residual demand is usually described as the residual load[10]. Thus a lower number of conventional plants has to be run to cover this residual load. As the price of electricity is set within the merit-order by the power plant with the highest marginal costs, a decrease of residual load results in a reduction of the electricity price.

The impacts of wind energy generation on the electricity supply system can be divided in two main aspects[11]:

• Impacts on system efficiency
• Impacts on reliability of the electricity supply system

## Impacts on System Efficiency

The decline of residual load – caused by fed-in wind energy – depends on the prevailing wind speed and the related electricity production of integrated wind turbines. Besides this reduction, the variability of the residual load increases considerably, because the availability of wind energy varies with wind speed. As a result plants for covering peak loads (e.g. gas turbines in Germany) are used less often and generally power plants are operated in part load more frequently. Output of conventional power plants has to be change more frequently and thus the required flexibility of the plants is increased[12].

Wind turbines replace conventional plants within the electricity supply and reduce consumption of fossil fuels and the emission of greenhouse-gases. The impacts on operation of conventional plants described above reduce this positive effect, because overall system-efficiency declines: Plants in part load operation have a lower efficiency and frequently start-up and shut down of plants causes additional fuel consumption for the related technical processes[11].
In case a large capacity of wind energy is already integrated into the electricity supply system, surpluses in supply can occur in case of high wind speeds. If the conventional power plants are already operated at minimum load and demand is generally low, it is possible, that electricity generated by wind turbines can not be fed into the grid without causing serious mismatches between demand and supply. In this case electricity production by wind turbines has to be regulated or shut-down[11].

## Impacts on Reliability of the Electricity Supply System

The reliability of an electricity supply system can be measured by the probability to cover the annual peak load by use of the installed power plant capacity in the system. More precise the risk of mismatch between supply and demand during peak load is evaluated. To calculate this probability the secured capacity available in a system must be known. To calculate the secured capacity, probability of plant outages is applied and the corresponding capacity is subtracted. Furthermore outages caused by planned revisions are taken into account[6].

To ensure a reliable supply system, the available secured capacity must be able to cover the annual peak load. Thus the installed capacity must include a surplus corresponding to the difference between installed and secured capacity.
Caused by their significantly higher variability of electricity production, wind turbines are considered as plants with a considerably lower secured capacity compared to conventional fossil fuel plants. Due to this fact, it is important to analyse how much conventional capacity can be replaced by wind energy within the system, without influencing system reliability.

By means of the so-called Capacity Credit (CC) conventional capacity and wind turbine capacity can be compared concerning impacts on system reliability.

## The Capacity Credit (CC)

The calculation of the CC (given in MW) is based on the probability of wind turbine availability during peak load periods. In this way the share of wind turbine capacity, which can be considered as secured capacity for covering peak load can be determined[13][14]. As wind turbines are a non-dispatchable source of electricity production, the resulting CC for wind turbines is subtantially lower than the secured capacity of conventional power plants. Thus to ensure system reliability in a system with a large wind energy share, a large surplus capacity must be installed within the system[11].
This mechanism should be clarified by a short example:

• We consider an electricity supply system with a annual peak load of 70 GW and and electricity demand of 350 TWh annualy
• By policy objective 10 % of demand – 35 TWh – should be covered by wind turbines.
• The average capacity factor (CF) is assumed to be 0,3

Under these assumption a wind turbine capacity of 35000 GWh/8760 h * 0.3 = 13 GW is necessary to generated the amount of energy (35 TWh). In comparison 5,3 GW of conventional capacity are necessary for this task (assuming a CF of 0,75 for conventional plants)[3].

• It should be further assumed for the example, that an installed capacity of 84 GW is needed to ensure the availability of 70 GW during annual peak load. Thus there is a surplus of 20 % capacity installed to ensure system reliability.

Following this calculation, it should be possible to replace 5,3 GW of conventional capacity by 13 GW of wind energy capacity. However this is not feasible, because the CF only provides information about the average availability of wind turbine capacity during a year. To calculate the secured capacity available to cover peak load, the probability of availability of wind turbine capacitiy during peak load periods must be considered. This probability – as explained above – is used for the calculatoin of the CC. Due to variability and limited predictability of wind energy production, the CC of wind turbines is significantly lower than the CF. Thus a even smaller share of conventional capacity could be replaced directly by wind energy. In this is example the CC is calculated to be 0,23 and a share of 3 GW of conventional capacity can be replaced. The remaining 2,3 GW of conventional capacity must be kept as reserve capacity within the system.[3]
The CC is calculated by statistical methods using the following characteristic of the electricity supply system:

• Occurrence and duration of peak load periods as well as the correlation between peak load and wind turbine output. A positive correlation increases the value of the CC, while a negative correlation has a declining impact. For example there is a seasonal correlation of the availability of wind energy and demand in many countries, because wind speeds are higher during winter months when electricity demand reaches peak values, too.
• Variability of demand during peak load periods. More precisely the expected demand as well as the possible range of demand levels is taken into account.
• The expected output as well as the range of possible output levels of conventional plants is considered
• The range of possible output of installed wind turbines during peak load periods. In principle the output could vary between zero and 100 % of installed capacity. For the calculation of the CC the expected value and its Variance is taken into account. A decrease in Variance results in an increase in CC.

The CC of 0,23 (or 230 kW of 1 MW) used in the example must be regarded as a very high value for this variable. A study investigating impacts of wind energy integration in the German electricity system (conducted by the German energy agency (DENA)[6]) uses significantly lower CC values of 0,07.

# References

1. Gatzen C (2008) The Economics of Power Storage - Theory and Empirical Analysis for Central Europe, Schriften des Energiewirtschaftlichen Instituts zu Köln, vol 63. Oldenbourg Industrieverlag
2. Jarass L, Obermair G, Voigt W (2009) Windenergie – Zuverlässige Integration in die Energieversorgung. Springer
3. Freris L, Infield D (2008) Renewable energy in power systems. John Wiley+Sons, Ltd Cite error: Invalid <ref> tag; name "Freris L, Infield D (2008)" defined multiple times with different content Cite error: Invalid <ref> tag; name "Freris L, Infield D (2008)" defined multiple times with different content Cite error: Invalid <ref> tag; name "Freris L, Infield D (2008)" defined multiple times with different content Cite error: Invalid <ref> tag; name "Freris L, Infield D (2008)" defined multiple times with different content Cite error: Invalid <ref> tag; name "Freris L, Infield D (2008)" defined multiple times with different content Cite error: Invalid <ref> tag; name "Freris L, Infield D (2008)" defined multiple times with different content
4. Burton, T. et al (2001) Wind Energy Handbook, Wiley+Sons
5. Freris L, Infield D (2008) Renewable energy in power systems. John Wiley + Sons, Ltd
6. Dena (2005) Konzept für eine stufenweise Entwicklung des Stromnetzes in Deutschland zur Anbindung und Integration von Windkraftanlagen Onshore und Offshore unter Berücksichtigung der Erzeugungs- und Kraftwerksentwicklungen sowie der erforderlichen Regelleistung. In: Energiewirtschaftliche Planung für die Netzintegration von Windenergie in Deutschland an Land und Offshore bis zum Jahr 2020 - Netzstudie I, Deutsche Energie Agentur [[1]] Cite error: Invalid <ref> tag; name "www.dena.de" defined multiple times with different content
7. Dena (2005) Konzept für eine stufenweise Entwicklung des Stromnetzes in DeutschlandfckLRzur Anbindung und Integration von Windkraftanlagen Onshore und Offshore unter BerücksichtigungfckLRder Erzeugungs- und Kraftwerksentwicklungen sowie der erforderlichenfckLRRegelleistung. In: Energiewirtschaftliche Planung für die Netzintegration von WindenergiefckLRin Deutschland an Land und Offshore bis zum Jahr 2020 - Netzstudie I, DeutschefckLREnergie Agentur
8. Gross R, Heptonstall P, Anderson D, Green T, Leach M, Skea J (2006) The costs andfckLRimpacts of intermittency: An assessment of the evidence on the costs and impacts offckLRintermittent generation on the British electricity network. UK Energy Research Center [[2]]
9. Benitez LE, Benitez PC, van Kooten GC (2008) The economics of wind power with energyfckLRstorage. Energy Economics 30:1973–1989
10. Sensfuß F, Ragwitz M, Genoese M (2008) The merit-order effect: A detailed analysis offckLRthe price effect of renewable electricity generation on spot market prices in Germany.fckLREnergy Policy 36:3086–3094
11. Gross R, Heptonstall P, Anderson D, Green T, Leach M, Skea J (2006) The costs and impacts of intermittency: An assessment of the evidence on the costs and impacts of intermittent generation on the British electricity network. UK Energy Research Center [[3]] Cite error: Invalid <ref> tag; name "Gross, 2006" defined multiple times with different content Cite error: Invalid <ref> tag; name "Gross, 2006" defined multiple times with different content Cite error: Invalid <ref> tag; name "Gross, 2006" defined multiple times with different content
12. Sensfuß F, Ragwitz M, Genoese M (2008) The merit-order effect: A detailed analysis offckLRthe price effect of renewable electricity generation on spot market prices in Germany.fckLREnergy Policy 36:3086–3094
13. For a detailed description of one capacity credit calculation method, see Dena (2005) Konzept für eine stufenweise Entwicklung des Stromnetzes in Deutschland zur Anbindung und Integration von Windkraftanlagen Onshore und Offshore unter Berücksichtigung der Erzeugungs- und Kraftwerksentwicklungen sowie der erforderlichen Regelleistung. In: Energiewirtschaftliche Planung für die Netzintegration von Windenergie in Deutschland an Land und Offshore bis zum Jahr 2020 - Netzstudie I, Deutsche Energie Agentur, S.238ff. [[4]]
14. For an practical example for capacity credit calculation see the GTZ feasibility studies for wind park sites in Ethiopia - GTZ (2006) Feasibility Study for Windpark Development in Ethiopia and Capacity Building - Ashegoda Wind Park Site Final Report, retrieved 25.7.2011 [[5]]