Estimation of Wind Energy Production

The calculation of the wind resources on-site and the corresponding energy production are based on the assessment of wind potentials by anemometric measurement. The wind data is processed software packages to calculate the expected wind energy yield for the proposed site. 

Meteorology

Generally, wind flows are large-scale balancing air movements in the atmosphere between high pressure and low pressure-areas, in some cases superposed by local balancing movements. The pressure differences are caused, and driven by, the solar heating of the Earth s atmosphere, landmasses and water bodies. Warm air is rising, leaving a low pressure area at the surface and causing high pressure areas within higher layers of the atmosphere where the air is cooling down and falling to lower layers with respective pressure effects.

Since the balancing air movements also run near the earth s surface they are significantly affected by the surface roughness and the orographic terrain structure.

Roughness is a quantitative description for the friction of the surface causing a slowdown of the near-surface air flow. Water and land without vegetation has a low roughness and therefore a minimal effect to the wind, forests or cities have a high roughness.

On top of a hill, the air flow is compressed and thus the wind has a higher energy density compared to the same air flow over flat terrain. Furthermore, valleys and similar terrain structures can act as a blast pipe, concentrating the air flow. Behind mountain ridges and inside valleys the air flow is disturbed by recirculation and shading effects.

The influence of the topography is shown in the energy calculation results in Annex C 2 in Production Analysis 

Software Basics

WindPro

The WindPRO philosophy is object orientated projecting. A wind park project consists of a number of objects, whereby the wind turbines are key elements. Objects are: wind turbines, wind monitoring stations, local obstacles etc. Some of the objects directly determine the wind energy, others focus on the environmental aspects and yet some others can also influence the feasibility of the project. The characteristics of the objects are combined with the terrain data such as the surface roughness maps and the height level contour lines and serve as basic input data for the energy calculations with WAsP, which is the WindPRO integrated meteorological simulation model. 

WAsP

WAsP is a software program for predicting wind climate and energy yield of wind turbines. The predictions are based on wind data measured on site or from stations in the same region and considers the effects of the surrounding terrain to the wind flow (topography, surface description, obstacles). WAsP uses the wind atlas methodology. In a first step the influence of the terrain to the wind flow is calculated, creating a generalised regional wind climate.

In a reverse process, this generalised regional wind climate (called wind statistic) is then applied to topography, surface description and obstacles at the vicinity of each individual wind turbine, providing the wind flow at this point even if the wind data has measured in some distance which can be, depending on the terrain, up to several kilometres.

Model Input Parameters

Besides the processed wind data, important input parameters for the energy yield calculation model are as described the terrain description, comprising of the orographical (topographical) model and the description of the earth´s surface (roughness description).

Orography

A method to gather data describing the orographical terrain is the analysis of data collected by satellites. As an example the SRTM -Shuttle Radar Topography Mission data base – provided by the US Geological Survey – scanned the earth´s surface between 60° latitude north and 54° latitude south, with a resolution of 90 x 90 m.

The data in between these points can be interpolated using the WindPro software to gain the topographical model of the proposed site, with a height contour density of 5 metres, as shown in Figure 1 (the example shows the orographic map of the Ashegoda site in Ethipia, where a feasibility study for a wind park has been conducted by German Technical Cooperation (GTZ)).

Figure 1: SRTM height contour map of Ashegoda wind park site in Ethiopia

Besides this advanced method of gathering topographical data, national or regional institutions can be asked for topographical maps of the area. The developers have to take care, whether the maps are available in an appropriate scale. Sources should be compared regarding accuracy and potential failures.

The height data is than processed to a three-dimensional digital elevation model of the wind farm site. An example for the Ashegoda site is shown in figure 2.

Three-dimensional digital elevation model of Ashegoda site, view from south-western direction

Roughness

For the model simulations the roughness classification for the surface in close proximity to the wind farm site is derived from topographical maps, data obtained during site visits as well as aerial photos of the region. A basic description of the roughness classes is given in the following (roughness length is a second roughness description unit), it has to be noted that the roughness class is a defined value which can not be measured directly. The roughness length describes the height where the wind speed in a logarithmic wind profile is becoming zero; the coarser the surface, the higher the roughness length. 

Roughness classes

Roughness class	Roughness length	Relative energy	Description of surface
0	0,0002	100	Water areas
0,5	0,0024	73	Mixed Water and land area of very smooth land
1	0,03	52	Open farmland with no crossing hedges and with scattered buildings. Only smooth hills
1,5	0,055	45	Farmland with some buildings and crossing hedges of 8m height and about 1250 m apart.
2	0,10	39	Farmland with some buildings and crossing hedges of 8m height and about 800 m apart.
2,5	0,20	31	Farmland with some buildings and crossing hedges of 8m height and about 250 m apart.
3	0,40	24	Villages, small towns, very closed farmladn with many or high hedges, Forrest, many abrupt orographic changes.
3,5	0,80	18	Large towns, cities with extended build-up areas
4	1,6	13	Large cities with build-up areas and high buildings

As an example for a roughness description the map of Ashegoda site is presented in the following Figure 3. 

Figure 3: Roughness map for Ashegoda wind park site in Ethiopia

Wind Shear

In many assessments of the wind potential the upper anemometers of the wind measurement are installed at a height of 40 m above ground while the hub height of modern wind turbines today often reaches heights between 55 m and 60 m above ground level. To estimate the wind regime at hub height of the wind turbines (the WAsP model simplifies the wind speed distribution over the rotor as concentrated to the hub height) the wind speed is extrapolated according to the following formula:

$v_{new}=v_{old}\cdot ({\frac {h_{new}}{h_{old}}})^{\gamma }$

Whereas $\gamma$ is the Power Law Exponent or Wind Gradient which is depending on the roughness of the terrain, the thermical lamination of the atmosphere, the wind speed itself and the height above ground. The exponent must be calculated sectorwise for the wind park site. This can be done by the WindPro-Software package from the measured wind data at the heights of 10 m a.g.l. respectively 40 m a.g.l..

The wind gradients for the twelve wind distribution sectors describe the wind speed at different heights for all wind directions diveded in sectors of 30°. An example for a calculated wind profile (increase of the wind speed with height) for the main wind direction of this site (sector south-southeast) is displayed in Figure 5.

Figure 4:Wind profile of Ashegoda wind park site (main wind direction south-southeast)

Combining considerations of terrain and roughness, the wind profile for the area of each individual wind turbine is then calculated by WAsP. The extrapolation from 40 m measuring height to 60 m hub height can be considered as reasonable but a further increase of the wind speed for hub heights of 80 m and more is not stringent as the power law is not suitable for height extrapolations over this range. 

Wind Turbine Parameters

To estimate the performance of different turbine types for the development of a new project usually several scenarios using different turbine types are calculated. Important turbine parameters, which should be included are hub height, nominal power and rotor diameter.

Power Curve and Air Density

The Power curve of a wind turbine is an important parameter, describing the relation between the wind speed on site and the respective electrical energy output. Power curves and ct-values (a parameter for the calculation of the wake effect) of the turbines under consideration are applied for the energy calculation. Power curves which had been measured by independent institutions are of higher quality than calculated ones. Due to the fluctuations of both the characteristics of the wind turbine components, and the measuring conditions power curves of different measurements differing slightly between each other.

Several manufacturers are thus providing power curves which are calculated from the results of several measured ones; the performance of these calculated power curves might be contractually guaranteed by the manufacturers.

During the calculation of the energy yield, the power curves, given for the standard conditions of air density = 1.225 kg/m3 are adapted to the air density of each individual turbine location at hub height, with the transformed power curves for the average air density. The air density can be calculated by WindPro for each individual wind turbine according to the site conditions, height above sea level plus the hub height of the turbines (e.g. 57 m / 60 m) and an annual average temperature level. As verification, the calculated adaptations for air density at the turbine sites should be compared to information provided by nearby meteorological stations. Figure 5 shows the power curves of several wind turbines at an air density of $\rho =1,225kg/m^{3}$.

Power curves for wind turbines proposed for the Ashegoda wind park in Ethiopia

As can be clearly seen, the Enercon E-53 and Gamesa G-58 wind turbines are generating more energy in the wind speed range from about 6 m/s to 12 m/s which occur more frequently then the other wind speed ranges, see the Weibull-distribution in Figure 7-10. This is mainly caused by be larger rotor diameter compared to the Enercon E-48 and Vestas V52 wind turbines. Figure 7-10: Weibull distribution of the correlated wind data of mast 1 Ashegoda 30_40m Feasibility Study for Windpark Development in Ethiopia and Capacity Building August 2006, Final Report - page 100 LI / GE6 25 0477 final report ashegoda 7.5 Losses and Uncertainties Meteorological phenomena can only be predicted to a certain limited degree. As a consequence it is not possible to make an exact forecast of the wind conditions even if longterm reference data (which can only represent the past) is used. Furthermore, data collection and processing is always afflicted with errors and inaccuracies as is every mathematical or physical model used to describe or predict real procedures. To compensate the inaccuracies in modelling approach and basic input data, it is advisable to use factors of safety to adjust, or discount the final output. Two blocks determine the factors of safety: losses and uncertainties. 7.5.1 Losses Losses are found on the whole energetic transformation chain from the rotor (kinetic energy) to the substation (electrical energy). The losses are simple add-ups to the total reduction of the calculated energy yield. In detail: 7.5.1.1 Park Efficiency After passing the rotor of a wind turbine, the wind has a decreased speed due to the kinetic energy taken away by the rotor and increased turbulence caused by the rotating rotor and the difference in speed compared to the undisturbed flow. Until the speed difference to undisturbed flow is not equalised, the result is a lower energy yield for the wind turbines following in the direction of the flow. These losses are called array or wake losses. The calculation of the wake losses of the wind turbines causing the so called shadowing effect between the wind turbines has been carried out using the wake model PARK which is part of the WindPRO software with the array losses of the individual wind turbine layouts of Ashegoda wind park calculated as follows: Feasibility Study for Windpark Development in Ethiopia and Capacity Building August 2006, Final Report - page 101 LI / GE6 25 0477 final report ashegoda Table 7-3: Array losses Ashegoda wind park Turbine type Array losses Enercon E-48 5.8% Vestas V52 5.0% Gamesa G58 5.3% Enercon E-53 5.7% The values are within an acceptable range for a wind park with several rows of closely spaced wind turbines. 7.5.1.2 Turbine Availability The turbine availability is the percentage of a year (i.e. 8760 hours) where the turbine is able to generate electrical energy while being connected to the grid. Reasons for the non-availability of a wind turbine are various, and include downtimes for regular maintenance and servicing, component failures (including defect sensors), overheating of components, repairs or exchange of components, as well as errors and downtimes of the superior electrical grid. The turbine availability is set to 95 % as a standard value according to LI´s long term experience, taking into account that no experience in the operation of windturbines in Ethiopia exists at present, and that all local staff have to be well educated and trained in the first operational years of the windpark. The proposed value is comparable with average values achieved in other wind parks abroad, and particularily in new wind markets where the total infrastructure for a high level operation of wind farms have to be build first. Later on and after the first years of sufficient turbine availability averages, the aim should be to raise the level up to 97 % which could be seen as a good value for the first wind parks in Ethiopia. To reach 98 % turbine availability as in high developed countries like in Europe, well educated and experienced staffs are needed. 7.5.1.3 Electrical Losses The electrical losses depend on the resistance of the conductors and on the current intensity. To assess the current intensity of the wind park the following methodology is used: the duration curve of the wind park for one year is approximated by a two stage approach. For 10% of the year (876 hours) full power is assumed and for the rest of the year (7,884 hours) the load is estimated to 25% of full load. Feasibility Study for Windpark Development in Ethiopia and Capacity Building August 2006, Final Report - page 102 LI / GE6 25 0477 final report ashegoda For this power pattern of the wind park, the turbine current is derived and the losses for the internal wind park cabling, and for the wind park cabling connection to the substation are calculated relative to the total energy output. For electrical losses LI has calculated the following values: - internal park cabling: 0.2% - internal park transmission lines: 0.5% - turbine transformers: 1.1% - transmission line 230kV: 0.5% - substation transformer 0.5% The total electrical losses of the park are estimated at 2.8% of that amount of electricity which is produced by the wind turbines. 7.5.1.4 Miscellaneous Losses In addition to the transmission losses and lost production due to reduced availability a number of other losses should be taken into account. The aerodynamic turbine performance described by the power curve is strongly depending on the profile and surface of the wind rotor blades. Blade fouling from dirt or insects on the surface of the blades lead to non-expected change of airfoil characteristics and to lower energy yield. The average air density of 17° in 2.400 m above sea level provides no thermal problems for the wind turbines. No effect of the low air density is to be expected than the reduced energy production. High wind control losses are caused by the turbine cut-in and cut-out strategy. The turbines will cut-off when cut-out wind speed is reached and will not re-cut-in until wind sped is below a defined wind speed level, lower than the cut-out level. A reduction factor of 0.1% to the gross energy output was applied to take these effects into account. 7.5.2 Wind Speed related Uncertainties Uncertainties cover the inaccuracy of the data processing from the measurement, the internal data processing and the long-term prediction. A percentage value describes the Feasibility Study for Windpark Development in Ethiopia and Capacity Building August 2006, Final Report - page 103 LI / GE6 25 0477 final report ashegoda standard deviation of scattering results around the expected true value. For the energy calculation, these wind speed-related uncertainty values have to be transformed to the energy production level. Additional uncertainties have to be determined for modelling and mathematical algorithms. 7.5.2.1 Uncertainties of the WAsP-Model The WAsP (Wind Atlas Analysis and Application Program) software is a proven tool used in the wind industry for more than 15 years. As every model it has limitations and uncertainties mainly due to the simplifications behind it which had been done to handle the calculations on desktop computers in an acceptable time frame. Mesoscalic meteorological models require powerful computers and a calculation time of several days. However, WAsP has been used for a considerable time worldwide and the uncertainties have been evaluated over the years. In case of Ashegoda, the existence of modestly shaped hills and ridges lead to a suffiecient quality of the calculation. Transfer Wind to Energy The discrete wind flow from discrete wind directions is simplified to 10-minute average values for 12 direction sectors and statistically preprocessed before being applied to the power curve. The uncertainty of this step can be set to 1%. Site modelling Consists basically of two input parameters: the topographical model and the surface description (roughness description). The topographical data is gained from the digital 1:12.500 map delivered by EEPCO to LI for the wind park area itself and from the SRTM (Shuttle Radar Topographical Mission) Satellite height data base for the vicinity of the site. Quality and resolution of both data are good, the uncertainty is low. As the surface structure of the earth in the area around Mekelle is not complex, it can be described with acceptable accuracy. The uncertainty of the Site Model is set accordingly to the below-average value of 2.5%. Flow modelling WasP has been developed for use in areas with only modestly shaped hills which is the case at Ashogoda site. The uncertainty of the flow modelling is set to the medium value of 3.0% . Wake modelling Feasibility Study for Windpark Development in Ethiopia and Capacity Building August 2006, Final Report - page 104 LI / GE6 25 0477 final report ashegoda The uncertainty of the selected wake model (N.O.Jensen) is low and as the area of the wind farm itself is nearly plain (no additional uncertainties due to the influence of the terrain) it can be set to 0.5%. wind-related uncertainties for the WAsP-model Source Uncertainty Comments Transfer Wind to Energy 1.0% typical value Site Model 2.5% below average Flow Model 3.0% medium average value Wake Model 0.5% typical value Uncertainty WAsP 4.1% To calculate the total uncertainty all single uncertainties can be considered as stochastically independent and the commonly used way of estimating the joint uncertainty of independent (un-correlated) uncertainties is to calculate the RMS (root mean square) value. Total wind speed related uncertainty WAsP = 0.012 0.0252 0.032 0.0052 0.041 7.5.2.2 Uncertainties of the Wind Data The reliability of the WAsP calculation is highly dependent on the quality of the input parameters of which wind data is the most important one. The collection and processing of wind date is subject to several uncertainties. Anemometer calibration Anemometers should be calibrated in order to secure that the measured wind speed equals the actual wind speed. The anemometers of the Ethiopian wind measurement campaign have been calibrated according to MEASNET standards, the calibration protocols have been handed over to LI. The assignment of the individual calibration protocols to the individual anemometers of the measuring campaign is not possible but as nothing significantly conspicuous has been detected the uncertainty of the calibration process can be set to the average value of 1.5 %. Feasibility Study for Windpark Development in Ethiopia and Capacity Building August 2006, Final Report - page 105 LI / GE6 25 0477 final report ashegoda Anemometer characteristics Describes the uncertainty of the quality the anemometer detects the wind flow and processes the values to digital data. Can be set to the lower value of 0.5% as calibrated first class anemometers have been used. Mounting error The anemometer has to be vertically mounted. The uncertainty describes the effect if this is not done properly. As can be seen in Figure 5-3, mast 13 Ashegoda II is not properly vertical aligned. For the other mast the mounting is more accurately. The average uncertainty for the mounting error is set to 1.0 %. Data recording Describes the uncertainties related to processing and storage of the data provided by the anemometer and the wind vane in the data logger. Set to 0.4 %. Terrain description Describes the uncertainty of the influence of the terrain to the measurement. Inclined wind flow and strong turbulence can not be measured accurately by a cup anemometer. At Ashegoda site, mast 4 Ashegoda I is located close to a steep descent in main wind direction (height difference 20 m), mast 13 Ashegoda II is situated on a small plateau on a modestly shaped ridge. The uncertainty for the terrain description is set to the average value of 1.5 %. Long term correlation The data used for the long term correlation as well as the MCP-Process includes uncertainties; as long-term reference data of 25 years is available the uncertainty for this category can be set to the moderate value of 3.0 %. This can be decreased when using measured long-term data near the site (NCEP data are recalculated data). To calculate the total uncertainty all single uncertainties can be considered as stochastically independent and the commonly used way of estimating the joint uncertainty of independent (un-correlated) uncertainties is to calculate the RMS value. The total uncertainty of 4.1 % refers to the wind speed at hub height for each single turbine. Feasibility Study for Windpark Development in Ethiopia and Capacity Building August 2006, Final Report - page 106 LI / GE6 25 0477 final report ashegoda Uncertainties for Wind Database Source Uncertainty Comments Anemometer calibration 1.5% typical average value, Anemometer characteristics 0.5% typical lower value, Mounting error 1.0% increased value Data recording 0.4% typical value Terrain description 1.5% modestly shaped terrain Long term correlation 3.0% data base satisfactorily Uncertainty Wind 3.9% Total uncertainty Wind Data = 0.0152 0.052 0.012 0.0042 0.0152 0.032 0.039 7.5.2.3 Total Wind related Uncertainty The total wind related uncertainty is the RMS value of Total uncertainty WAsP and Total uncertainty Wind which is 5.6%. 7.5.2.4 Uncertainties of the Power Curve It has to be considered that the power curve used for the gross energy calculation is also subject to uncertainties which had been described in chapter 7.4.1. Due to the non linear relation of mean wind speed and energy these uncertainties can not be integrated into the uncertainties of wind conditions but have to be dealt with separately. In chapter 7.5.3 the calculation of the uncertainties of the energy yield for the different wind turbine types is performed; the uncertainty of the power curve is, assuming the power performance of the turbine as independent of the energy deviation due to wind uncertainties, connected to the uncertainties of the energy yield by the following equation: Total uncertainty = 2 2 uncertainty energy yield uncertainty power curve Feasibility Study for Windpark Development in Ethiopia and Capacity Building August 2006, Final Report - page 107 LI / GE6 25 0477 final report ashegoda The turbine supplier usually gives a guarantee of 95 % of the energy values, which leads to an uncertainty to the predicted figures of 5 %; the actual guarantee value has to be negotiated with the manufacturer, the uncertainty can be adapted accordingly. This figure has been taken for every wind turbine type as it is sufficiently conservative for both calculated and measured power curves. 7.5.3 Uncertainties Energy Yield The interpretation of uncertainty in energy yield from the total uncertainty in wind speed is not straightforward. The theoretical cubic relation of wind speed and energy does not give a correct description of the phenomena. For the long term mean wind speed averaged over all turbine locations at hub height the average wind speed value is derived from the wind data processing. The uncertainty is equivalent to a reduction to the mean wind speed when considering the worst case. To translate this reduced mean wind speed into energy yield the parameters of a Weibull distribution are adapted and this new Weibull distribution is then applied to the individual turbine power curves. The results for the considered wind park layout can be found in the examinations in the following tables Deviation of Energy due to wind uncertainties , indicating an energy deviation due to the uncertainty in wind speed assessment. Feasibility Study for Windpark Development in Ethiopia and Capacity Building August 2006, Final Report - page 108 LI / GE6 25 0477 final report ashegoda 7.5.3.1 Enercon E-48 The transformation of the wind speed related uncertainties into the energy related uncertainty by appropriately reducing the wind speed at hub height leads to the following results displayed in Table 7-4: Table 7-4: Deviation of Energy due to wind uncertainties Mean wind speed [m/s] Deviation wind speed A-factor [m/s] k-factor Energy Yield [MWh/y] Deviation Energy calculated WAsP 8.78 0.0% 9.75 3.62 252,175 0.0% reduced wind speed; uncertainties taken into account 8.29 5.6% 9.20 3.62 217,290 13.83% Assuming the power performance of the turbine as independent of the energy deviation due to wind uncertainties, the total uncertainty for energy yield can be determined from the uncertainties of wind conditions (13.83 %) and power curve (5%) to 14.71 % ( (13.83)2 52 ). The analysis of uncertainties is an important step for the risk assessment of the project. From the predicted annual energy and from the total uncertainty on the energy level of 16.5 % the probability of exceeding of certain energy yields can be calculated by statistical methods. Applying a Gauss process for the statistic analysis, the calculated gross annual energy can be understood as the mean annual energy yield having the highest rate of probability of all single results. The uncertainty shall be understood as standard deviation of the expected results around the most probable event. Figure 7-11 displays the probabilities that a certain amount of annual electricity production is exceeded. Gross annual energy describes the energy yield as calculated and net annual energy the energy yield considering the losses and uncertainties. Feasibility Study for Windpark Development in Ethiopia and Capacity Building August 2006, Final Report - page 109 LI / GE6 25 0477 final report ashegoda 150,000 160,000 170,000 180,000 190,000 200,000 210,000 220,000 230,000 240,000 250,000 260,000 270,000 280,000 290,000 0.0% 10.0% 20.0% 30.0% 40.0% 50.0% 60.0% 70.0% 80.0% 90.0% 100.0% gross annual energy net annual energy Probability of Exceedance 50 % 75% 90% MWh/y 197,392 177,82 219,133 Figure 7-11: Probability of exceedance for Ashegoda wind park, Enercon E-48 layout Besides the uncertainties for wind conditions and power curve, the losses for electricity transmission (2.8 %) and reduced availability of the turbines (95 %) have also to be considered as constant factors, reducing the estimated energy yield. For the Enercon E-48 800kW wind turbine described within section 6.2 the energy calculations, the results for different levels of exceedance are displayed on the following table: Feasibility Study for Windpark Development in Ethiopia and Capacity Building August 2006, Final Report - page 110 LI / GE6 25 0477 final report ashegoda Table 7-5: Energy Calculations for Ashegoda Wind Park, Enercon E-48 layout Enercon E-48 800 kW; 57 m hub height at Ashegoda Wind Park Turbine Type Enercon E-48 Enercon E-48 Enercon E-48 Enercon E-48 Turbine Capacity kW 800 800 800 800 Number of WTG 86 86 86 86 Installed park capacity MW 68.8 68.8 68.8 68.8 Hub Height m 57 57 57 57 Rotor Diameter m 48 48 48 48 Specific Rotor Area m2/kW 2.26 2.26 2.26 2.26 Probability % 50 75 90 95 Gross energy production MWh/y 252,175 227,155 204,637 191,160 Wind park array losses % 5.8 5.8 5.8 5.8 Turbine availability % 95.0 95.0 95.0 95.0 Electrical losses % 2.8 2.8 2.8 2.8 Miscellaneous losses % 0.10 0.10 0.10 0.10 Net Output MWh/y 219,133 197,392 177,824 166,113 Specific Energy Production kWh/m2 1,408 1,268 1,143 1,067 Full load hours h/a 3,185 2,869 2,585 2,414 Capacity Factor % 36.4 32.8 29.5 27.6 Feasibility Study for Windpark Development in Ethiopia and Capacity Building August 2006, Final Report - page 111 LI / GE6 25 0477 final report ashegoda 7.5.3.2 Vestas V52 The transformation of the wind speed related uncertainties into the energy related uncertainty by appropriately reducing the wind speed at hub height leads to the following results displayed in Table 7-4: Table 7-6: Deviation of Energy due to wind uncertainties Mean wind speed [m/s] Deviation wind speed A-factor [m/s] k-factor Energy Yield [MWh/y] Deviation Energy calculated WAsP 8.84 0.0% 9.81 3.62 248,854 0.0% reduced wind speed; uncertainties taken into account 8.35 5.6% 9.26 3.62 218,642 12.14% Assuming the power performance of the turbine as independent of the energy deviation due to wind uncertainties, the total uncertainty for energy yield can be determined from the uncertainties of wind conditions (12.14 %) and power curve (5 %) to 13.13 % ( (12.14)2 52 ). The analysis of uncertainties is an important step for the risk assessment of the project. From the predicted annual energy and from the total uncertainty on the energy level of 15.10% the probability of exceeding of certain energy yields can be calculated by statistical methods. Applying a Gauss process for the statistic analysis, the calculated gross annual energy can be understood as the mean annual energy yield having the highest rate of probability of all single results. The uncertainty shall be understood as standard deviation of the expected results around the most probable event. Figure 7-12 displays the probabilities that a certain amount of annual electricity production is exceeded. Gross annual energy describes the energy yield as calculated and net annual energy the energy yield considering the losses and uncertainties. Feasibility Study for Windpark Development in Ethiopia and Capacity Building August 2006, Final Report - page 112 LI / GE6 25 0477 final report ashegoda 150,000 160,000 170,000 180,000 190,000 200,000 210,000 220,000 230,000 240,000 250,000 260,000 270,000 280,000 0.0% 10.0% 20.0% 30.0% 40.0% 50.0% 60.0% 70.0% 80.0% 90.0% 100.0% gross annual energy net annual energy Probability of Exceedance 50 % 75% 90% MWh/y 198,771 181,38 218,084 Figure 7-12: Probability of exceedance for Ashegoda wind park, Vestas V52 layout Besides the uncertainties for wind conditions and power curve, the losses for electricity transmission (2.8 %) and reduced availability of the turbines (95 %) have also to be considered as constant factors, reducing the estimated energy yield. For the Vestas V52 850kW wind turbine described within section 6.2 the energy calculations, the results for different levels of exceedance are displayed on the following table: Feasibility Study for Windpark Development in Ethiopia and Capacity Building August 2006, Final Report - page 113 LI / GE6 25 0477 final report ashegoda Table 7-7: Energy Calculations for Ashegoda Wind Park, Vestas V52 layout Vestas V52 850 kW; 60 m hub height at Ashegoda Wind Park Turbine Type Vestas V52 Vestas V52 Vestas V52 Vestas V52 Turbine Capacity kW 850 850 850 850 Number of WTG 86 86 86 86 Installed park capacity MW 73.1 73.1 73.1 73.1 Hub Height m 60 60 60 60 Rotor Diameter m 52 52 52 52 Specific Rotor Area m2/kW 2.50 2.50 2.50 2.50 Probability % 50 75 90 95 Gross energy production MWh/y 248,854 226,816 206,981 195,110 Wind park array losses % 5.0 5.0 5.0 5.0 Turbine availability % 95.0 95.0 95.0 95.0 Electrical losses % 2.8 2.8 2.8 2.8 Miscellaneous losses % 0.10 0.10 0.10 0.10 Net Output MWh/y 218,084 198,771 181,388 170,985 Specific Energy Production kWh/m2 1,194 1,088 993 936 Full load hours h/a 2,983 2,719 2,481 2,339 Capacity Factor % 34.1 31.0 28.3 26.7 Feasibility Study for Windpark Development in Ethiopia and Capacity Building August 2006, Final Report - page 114 LI / GE6 25 0477 final report ashegoda 7.5.3.3 Gamesa G 58 The transformation of the wind speed related uncertainties into the energy related uncertainty by appropriately reducing the wind speed at hub height leads to the following results displayed in Table 7-4: Table 7-8: Deviation of Energy due to wind uncertainties Mean wind speed [m/s] Deviation wind speed A-factor [m/s] k-factor Energy Yield [MWh/y] Deviation Energy calculated WAsP 8.87 0.0% 9.84 3.62 299,064 0.0% reduced wind speed; uncertainties taken into account 8.37 5.6% 9.28 3.62 265,865 11.10% Assuming the power performance of the turbine as independent of the energy deviation due to wind uncertainties, the total uncertainty for energy yield can be determined from the uncertainties of wind conditions (11.10 %) and power curve (5 %) to 12.17 % ( (11.10)2 52 ). The analysis of uncertainties is an important step for the risk assessment of the project. From the predicted annual energy and from the total uncertainty on the energy level of 14.02% the probability of exceeding of certain energy yields can be calculated by statistical methods. Applying a Gauss process for the statistic analysis, the calculated gross annual energy can be understood as the mean annual energy yield having the highest rate of probability of all single results. The uncertainty shall be understood as standard deviation of the expected results around the most probable event. Figure 7-13 displays the probabilities that a certain amount of annual electricity production is exceeded. Gross annual energy describes the energy yield as calculated, and net annual energy the energy yield considering the losses and uncertainties. Feasibility Study for Windpark Development in Ethiopia and Capacity Building August 2006, Final Report - page 115 LI / GE6 25 0477 final report ashegoda 190,000 200,000 210,000 220,000 230,000 240,000 250,000 260,000 270,000 280,000 290,000 300,000 310,000 320,000 330,000 340,000 0.0% 10.0% 20.0% 30.0% 40.0% 50.0% 60.0% 70.0% 80.0% 90.0% 100.0% gross annual energy net annual energy Probability of Exceedance 50 % 75% 90% MWh/y 239,804 220,49 261,258 Figure 7-13: Probability of exceedance for Ashegoda wind park, Gamesa G58 layout Besides the uncertainties for wind conditions and power curve, the losses for electricity transmission (2.8 %) and reduced availability of the turbines (95 %) have also to be considered as constant factors, reducing the estimated energy yield. For the Gamesa G58 850kW wind turbine described within section 6.2 the energy calculations, the results for different levels of exceedance are displayed on the following table: Feasibility Study for Windpark Development in Ethiopia and Capacity Building August 2006, Final Report - page 116 LI / GE6 25 0477 final report ashegoda Table 7-9: Energy Calculations for Ashegoda Wind Park, Gamesa G58 layout Gamesa G58 850 kW; 60 m hub height at Ashegoda Wind Park Turbine Type Gamesa G58 Gamesa G58 Gamesa G58 Gamesa G58 Turbine Capacity kW 850 850 850 850 Number of WTG 86 86 86 86 Installed park capacity MW 73.1 73.1 73.1 73.1 Hub Height m 60 60 60 60 Rotor Diameter m 58 58 58 58 Specific Rotor Area m2/kW 3.11 3.11 3.11 3.11 Probability % 50 75 90 95 Gross energy production MWh/y 299,064 274,505 252,402 239,174 Wind park array losses % 5.3 5.3 5.3 5.3 Turbine availability % 95.0 95.0 95.0 95.0 Electrical losses % 2.8 2.8 2.8 2.8 Miscellaneous losses % 0.10 0.10 0.10 0.10 Net Output MWh/y 261,258 239,804 220,494 208,939 Specific Energy Production kWh/m2 1,150 1,055 970 920 Full load hours h/a 3,574 3,280 3,016 2,858 Capacity Factor % 40.8 37.4 34.4 32.6 Feasibility Study for Windpark Development in Ethiopia and Capacity Building August 2006, Final Report - page 117 LI / GE6 25 0477 final report ashegoda 7.5.3.4 Enercon E-53 The transformation of the wind speed related uncertainties into the energy related uncertainty, by appropriately reducing the wind speed at hub height, leads to the following results displayed in Table 7-4: Table 7-10: Deviation of Energy due to wind uncertainties Mean wind speed [m/s] Deviation wind speed A-factor [m/s] k-factor Energy Yield [MWh/y] Deviation Energy calculated WAsP 8.79 0.0% 9.75 3.62 286,452 0.0% reduced wind speed; uncertainties taken into account 8.30 5.6% 9.20 3.62 251,976 12.04% Assuming the power performance of the turbine as independent of the energy deviation due to wind uncertainties, the total uncertainty for energy yield can be determined from the uncertainties of wind conditions (12.04 %) and power curve (5 %) to 13.03 % ( (12.04)2 52 ). The analysis of uncertainties is an important step for the risk assessment of the project. From the predicted annual energy and from the total uncertainty on the energy level of 14.88 % the probability of exceeding of certain energy yields can be calculated by statistical methods. Applying a Gauss process for the statistic analysis, the calculated gross annual energy can be understood as the mean annual energy yield having the highest rate of probability of all single results. The uncertainty shall be understood as standard deviation of the expected results around the most probable event. Figure 7-14 displays the probabilities that a certain amount of annual electricity production is exceeded. Gross annual energy describes the energy yield as calculated and net annual energy the energy yield considering the losses and uncertainties. Feasibility Study for Windpark Development in Ethiopia and Capacity Building August 2006, Final Report - page 118 LI / GE6 25 0477 final report ashegoda 180,000 190,000 200,000 210,000 220,000 230,000 240,000 250,000 260,000 270,000 280,000 290,000 300,000 310,000 320,000 0.0% 10.0% 20.0% 30.0% 40.0% 50.0% 60.0% 70.0% 80.0% 90.0% 100.0% gross annual energy net annual energy Probability of Exceedance 50 % 75% 90% MWh/y 227,278 207,56 249,183 Figure 7-14: Probability of exceedance for Ashegoda wind park, Enercon E-53 layout Besides the uncertainties for wind conditions and power curve, the losses for electricity transmission (2.8 %) and reduced availability of the turbines (95 %) have also to be considered as constant factors, reducing the estimated energy yield. For the Enercon E-53 800kW wind turbine described within section 6.2 the energy calculations, the results for different levels of exceedance are displayed on the following table: Feasibility Study for Windpark Development in Ethiopia and Capacity Building August 2006, Final Report - page 119 LI / GE6 25 0477 final report ashegoda Table 7-11: Energy Calculations for Ashegoda Wind Park, Enercon E-53 layout Enercon E-53 800 kW; 57 m hub height at Ashegoda Wind Park Turbine Type Enercon E-53 Enercon E-53 Enercon E-53 Enercon E-53 Turbine Capacity kW 800 800 800 800 Number of WTG 86 86 86 86 Installed park capacity MW 68.8 68.8 68.8 68.8 Hub Height m 57 57 57 57 Rotor Diameter m 53 53 53 53 Specific Rotor Area m2/kW 2.76 2.76 2.76 2.76 Probability % 50 75 90 95 Gross energy production MWh/y 286,451 261,271 238,608 225,045 Wind park array losses % 5.7 5.7 5.7 5.7 Turbine availability % 95.0 95.0 95.0 95.0 Electrical losses % 2.8 2.8 2.8 2.8 Miscellaneous losses % 0.10 0.10 0.10 0.10 Net Output MWh/y 249,183 227,278 207,564 195,765 Specific Energy Production kWh/m2 1,313 1,198 1,094 1,032 Full load hours h/a 3,622 3,303 3,017 2,845 Capacity Factor % 41.3 37.7 34.4 32.5 Feasibility Study for Windpark Development in Ethiopia and Capacity Building August 2006, Final Report - page 120 LI / GE6 25 0477 final report ashegoda 7.6 Summary The four layouts scenarios for Ashegoda wind park show the following energy yield, related to the P75 value: Net Energy Production, 198,771 Net Energy Production, 197,392 Net Energy Production, 239,804 Net Energy Production, 227,278 0.000 50.000 100.000 150.000 200.000 250.000 300.000 Energy in MW/h Vestas V52 Enercon E-48 Gamesa G58 EnerconE-53 Probability 75% Miscellaneous losses Electrical losses Turbine availability Wind park array losses Net Energy Production Gross Energy production 226,816 KW/h Gross energy production 274,505 KW/h Gross energy production 227,155 KW/h Gross energy production 261,271 KW/h Figure 7-15: P75 energy production of the different scenarios of Ashegoda wind park The higher energy yield calculated for the Gamesa G58 and Enercon E-53 wind turbines is mainly related to the larger rotor diameter of these turbines compared to the Enercon E-48 and Vestas V52 turbines. The focusing to the generated energy yield however is not sufficient. Investment costs, indicated by the ratio specific investment costs ( per kWh) are more significant, for details refer to the economical part of the Feasibility Study for the presented specific data in per kWh.