TUGE Energia OÜ POWER PERFORMANCE TEST REPORT · 2019. 5. 20. · POWER PERFORMANCE TEST REPORT TUGE Energia OÜ Intertek Report: 103254243CRT-008 Version: 6-March-2017 Page 6 of

TUGE Energia OÜ POWER PERFORMANCE TEST REPORT

SCOPE OF WORK Power Performance Test Report for the TUGE10 turbine tested at the Intertek SEMKO Small Wind test site / foundation 2 / Lilla Båtskär ÅLAND REPORT NUMBER 103254243CRT-008 ISSUE DATE 17 May 2019 PAGES 31 DOCUMENT CONTROL NUMBER GFT-OP-10a © 2017 INTERTEK

POWER PERFORMANCE TEST REPORT

3933 U.S. Route 11 Cortland, NY 13045 Telephone: 607-753-6711 Facsimile: 607-753-1045 www.intertek.com/wind

Version: 6-March-2017 Page 2 of 31 GFT-OP-10a

17-May-2019 Intertek Report No. 103254243CRT-008 Intertek Sweden Project No. 1717503

Intertek US Project No. G103254243 Indrek Gregor TUGE Energia OÜ Ph: +372 53 077 822 Mustamäe tee 4 10621 Tallinn, Estonia Email: [email protected] Subject: Power Performance Test Report for the TUGE10 turbine tested at the Lilla Båtskär / Åland test site. Dear Mr. Gregor, This report represents the results of the evaluation and tests of the above referenced equipment to the requirements contained in the following standard: AWEA 9.1 American Wind Energy Association Small Wind Turbine Performance and Safety Standard

First Edition; December 2009

IEC 61400-2 Wind turbines – Part 2: Small wind turbines

Third edition; December 2013

This investigation was authorized through signed Proposal# Qu-00821511-0, dated 21 September 2017, and is identified within Intertek Sweden as Project No. 1717503, and Intertek US as Project No. G103254243. Power performance testing began on February 6, 2018 and data collection completed on December 17, 2018. This Test Report completes the Power Performance testing phase of the TUGE10 wind turbine covered under Intertek Project No. G103254243. If there are any questions regarding the results contained in this report, or any of the other services offered by Intertek, please do not hesitate to contact your dedicated Intertek Project Manager.

Completed by: Sean Traynor Reviewed by: Steven Pasternack Title: Project Engineer Title: Senior Staff Engineer Signature: Signature Date 5/17/2019 Date: 5/17/2019

Please note: this Test Report on its own does not represent authorization for the use of any Intertek certification marks.


TUGE Energia OÜ Intertek Report: 103254243CRT-008


Wind Turbine Generator System Power Performance Test Report

for the

TUGE10

at

Lilla Båtskär / Åland




SECTION 1.0 TEST SUMMARY This test was conducted in accordance with the American Wind Energy Association Small Wind Turbine

Performance and Safety Standard dated December, 2009. The power performance test was also conducted in accordance with the first edition of the International Electrotechnical Commission’s (IEC) 61400-12-1

Power performance measurements of electricity producing wind turbines, dated December 2005. Hereafter, these testing standards and their procedures are referred to as the “Standards.” For the power performance test, and the results contained within this report, the following considerations apply:

• The turbine system is connected to the electrical network at the test site via a subpanel. All wiring and components on the turbine side of this subpanel are considered part of the turbine system.

• The turbine system includes all control equipment including wiring between the up-tower

equipment and the equipment located in the data shed. The test configuration consists of: o Up-tower turbine assembly – Rotor assembly, nacelle housing, lightning arrestor, system

anemometer & vane, nacelle frame with yaw bearing, alternator, rotor shaft brake, yaw motor, yaw brake, alternator cooling fan, and up tower junction box

o Down-tower assembly – Monopole tower, down tower electrical cabinet (WT controller, inverter, turbine disconnect, grid disconnects), dump loads, and foundation

o Equipment inside data shed – Intertek subpanel with circuit breakers o Meteorological tower, test instrumentation, junction boxes and wiring, and data acquisition o Power measurement equipment; installed between the AC output of the inverter and the

Intertek subpanel referenced in 1 above The tower is a steel tube construction, hydraulically raised, and divided into 3 parts. The base is connected to a concreate foundation. The tower height is 18 m. The wire run from the base of the tower to the power measurement equipment in the data shed is an approximate wire run length of 81.5 meters (267.4 feet); which satisfies the required wire run length of greater than 8 rotor diameters, as specified in AWEA 9.1. Table 1 further defines the configuration of the wind turbine system tested for this report and also provides the manufacturers declared ratings and specifications. The power measurement equipment used for measurement of electric power consists of both a current transformer and power transducer used to measure current and voltage to determine electric power output in accordance with the Standards. The power measurement equipment is connected between the AC output of the grid-tie inverter and the Intertek subpanel. The location of power measurement equipment encompasses the combined consumption and production of the entire turbine system. A typical wiring diagram is shown in the Appendix, which matches the test turbine system installed at the test site. Figure 1 is the summary of database results from the Power Performance Test conducted on the TUGE10 kW. In Figure 1, power is normalized to sea-level air density. As defined by IEC 61400-12-1, one data set shall include all data points in the database (database A). The other data set shall exclude all data points where the turbine has stopped generating power due to cut-out at high wind speed (database B). During testing the TUGE10 turbine was not observed to stop generating power due to cut-out at high wind speeds. The amount of test data analyzed to produce Figure 1 is sufficient to meet the database requirements of the Standards. Table 1 identifies the configuration of the wind turbine system tested for this report. The power measurement equipment used for measurement of electric power consists of both a current transformer and power transducer used to measure current and voltage, to determine electric power output in accordance with the Standards. The location of power measurement equipment encompasses the combined consumption and production of the entire turbine system. Refer to Appendix A for wiring diagrams.




Bin Wind Bin Number of

Speed Power Data

(m/s) (W) Points (-)

0.54 -245.32 419 -31.001.01 -253.96 961 -4.871.52 -249.47 1664 -1.412.01 -243.45 2094 -0.602.50 -184.61 2357 -0.243.00 -37.91 2541 -0.033.50 233.57 2630 0.114.01 699.83 3158 0.22

Rated power 9432.44 W 4.50 1220.50 2969 0.27Cut-in wind speed: 3.50 m/s 5.01 2077.49 2892 0.33Cut-out wind speed: 25.00 m/s 5.50 3127.43 3277 0.38Rated wind speed 11.00 m/s 5.99 4222.67 2834 0.39Rotor diameter: 10.20 m 6.50 5284.93 2747 0.38Rotor swept area 81.71 m 2̂ 7.00 6204.45 2861 0.36Control type: Active 7.49 7012.10 2755 0.33Pitch setting: Fixed 7.99 7687.50 2503 0.30

8.50 8349.19 2460 0.27Site Conditions: 8.99 8905.39 2340 0.24

9.49 9326.43 1959 0.22Location: Lilla Båtskär, Finland 9.99 9503.26 1837 0.19Average air density: 1.226 kg/m^3 10.50 9498.47 1727 0.16Valid measurement sectors: 200-600 °True 10.99 9432.44 1580 0.14

280-300 11.49 9213.67 1427 0.1212.00 8838.21 1288 0.10

Test Statistics: 12.49 8405.05 1227 0.0912.99 7974.89 1177 0.07

Start date: 6-Feb-2018 13.50 7508.16 1123 0.06End date: 17-Dec-2018 13.99 7197.42 1046 0.05Amount of data collected: 1019 Hours 14.50 6751.43 915 0.04Highest bin filled: 19.00 m/s 15.00 6376.17 749 0.04

Yes 15.48 6147.06 572 0.0315.98 6102.76 382 0.0316.48 6121.81 247 0.0316.97 6163.85 150 0.0317.45 6180.25 105 0.0217.98 6261.54 72 0.0218.48 6282.85 40 0.0218.97 6315.63 33 0.02

Cp

Test completed?

Test Summary

Power Performance Test

Sea-Level Density Power Curve

Database A

Turbine Test Observations:

0.00

0.05

0.10

0.15

0.20

0.25

0.30

0.35

0.40

-1000.00

0.00

1000.00

2000.00

3000.00

4000.00

5000.00

6000.00

7000.00

8000.00

9000.00

10000.00

0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25

Cp

Ele

ctr

ic P

ow

er,

W

Wind speed (m/s)

Sea-Level Density Normalized Power Curve TUGE10

Power Cp

Figure 1 - Power curve summary




Turbine Manufacturer TUGE Energia OÜ

Model TUGE10

Rotor Diameter 10.2 m Hub Height 18.5 m

Swept Area 82 m2

IEC 61400-2 SWT Class Class I

Rated Electrical Power 9900 Watts

Cut-in Wind Speed 3,5 m/s

Cut-out Wind Speed 25 m/s

Rated Wind Speed 11.0 m/s

Survival Wind Speed 50 m/s

Rated Rotational Speed 69 RPM

Rotor Speed Range 0-80 RPM

Generator Identification TUGE Energia OÜ, GEN1069225 (serial number 001) Inverter Identification Orbital Grid Feed Inverter GFI-310K

Controller Identification Orbital TMC3

Number of Blades 3

Fixed or variable pitch Fixed

Blade Pitch Angle 0° at root

Blade Specification Fiberglass / polyester, 8.9° twist, 4900mm blade length, 2.29 m2 blade areas, 18

embedded nuts for mounting (10 mm / 8.8 grade), tip brakes

Hub type Rigid

Slip Ring Identification N/A

Slip Ring Specification N/A

Brake/Furl System Components and

Identification Rotor Brake: Intorq GmbH, BFK455-28

Table 1 - Manufacturer Turbine Specifications




SECTION 2.0 BACKGROUND The TUGE10 turbine is designed for grid-connected power delivery, with a rated power output of 9.9 kW. It is a horizontal-axis wind turbine that is specified as SWT Class I according to IEC 61400-2. The turbine’s control system uses an active yaw mechanism. The TUGE10 turbine utilizes a three-phase AC permanent magnet synchronous generator. Grid interconnect is provided by an Orbital control Power System, GFI-310K together with TMC3 controller. The tower is a steel tube construction hydraulically raised divided into 3 parts & base connected to a concreate foundation. The tower height is 18 m. The TUGE10 turbine is installed at test foundation 2 on Lilla Båtskär at the Intertek SEMKO Small Wind test site on Åland, Finland.

SECTION 3.0 TEST OBJECTIVE The purpose of the power performance test was to collect data that meet a set of clearly defined criteria to ensure that the data are of sufficient quantity and quality to determine the power performance characteristics of the wind turbine accurately. Such characteristics include the wind turbine’s power curve, annual energy production (AEP), and power coefficient.

SECTION 4.0 JUDGMENTS, EXCEPTIONS, AND DEVIATIONS No judgements or deviations were required for this evaluation.

SECTION 5.0 TEST SITE DESCRIPTION The test site has class I winds, and can accommodate turbines that produce 240V/400V, 50 Hz power. It is on an island in the edge of the archipelago of Åland Island, with previous use for the Coastal Pilots, near the township of Mariehamn. It was surveyed, analyzed and developed to be a test site for Intertek’s customers. The TUGE10 turbine was tested at station 2, which has no prominent obstructions in the valid measurement sector, resulting from obstacle assessment in accordance with the Standards. The meteorological equipment tower is due west, 20.4 m (66.9 ft) from the turbine, approximately 2.00 times the diameter of the rotor, and is within the required range of 2 – 4 rotor diameters as defined in the Standards. Figure 2 below is an aerial image that displays the final valid measurement sector resulting from the combination of obstacle assessment and site calibration in accordance with IEC 61400-12-1. The preliminary obstacle assessment yielded an initial valid measurement sector of 190-310 degrees true, but this was cut to a final valid sector of 200-260 & 280-300 degrees true as a result of site calibration. Site calibration was required due to the local terrain not satisfying the criteria within the terrain assessment requirements of the Standards. A circle indicating 20 rotor diameters is also shown on the map.




Figure 2 – Aerial view and final valid measurement sector of the TUGE10 test turbine

Site calibration was required due to the combination of average slope and terrain variations within 20 rotor diameters of the turbine tower. Table 2 below shows the results of the site calibration for the TUGE10 power performance test, where: - “Direction” = each 10-degree wind direction bin, in true degrees, considered during site calibration, - “Total Time” = total number of hours of data collected in each wind direction bin, - “Velocity < 8 m/s” = total number of hours where wind speeds are below 8 m/s in each wind direction bin, - “Velocity > 8 m/s” = total number of hours where wind speeds are above 8 m/s in each wind direction bin, - “Turbine Vel_avg” = average wind speed measured at the turbine location in each wind direction bin, - “Met Vel_avg” = average wind speed measured at the meteorological tower location in each wind direction bin, - “Ratio” = average flow correction factor due to terrain for each wind direction bin (ratio of wind speed at the wind turbine location divided by the wind speed at the meteorological tower location), - Red text = INVALID sector resulting from obstacle assessment, - Black text = VALID sector resulting from obstacle assessment, and - Blue shade = FINAL VALID sector resulting from site calibration




Direction Direction Avg Total Time Vel < 8 m/s Vel >8 m/sTurbine

Vel_avgMet Vel_avg Ratio

(° true) (°true) (hours) (hours) (hours) (m/s) (m/s)

0-10 9.08 0.55 0.55 0.00 3.66 3.96 0.9145

10-20 15.76 24.97 24.18 0.78 4.80 5.08 0.9349

20-30 24.59 27.05 26.78 0.27 4.13 4.48 0.9094

30-40 34.54 21.17 21.07 0.10 3.73 4.36 0.8487

40-50 45.20 18.88 18.88 0.00 3.72 4.68 0.7894

50-60 54.69 14.58 14.58 0.00 4.30 4.50 0.9465

60-70 64.72 8.62 8.62 0.00 3.88 4.06 0.9472

70-80 75.09 7.67 7.67 0.00 3.67 3.76 0.9726

80-90 84.83 6.00 6.00 0.00 3.26 3.44 0.9565

90-100 95.21 7.70 7.70 0.00 3.25 3.47 0.9270

100-110 106.07 27.72 27.70 0.02 4.55 4.72 0.9644

110-120 114.57 23.07 23.07 0.00 4.39 5.06 0.8734

120-130 125.42 19.30 19.15 0.15 5.13 5.62 0.9181

130-140 135.09 25.42 24.73 0.68 5.53 6.10 0.9131

140-150 144.88 31.78 29.68 2.10 5.57 5.51 1.0141

150-160 155.45 28.95 23.67 5.28 5.66 6.56 0.8631

160-170 165.06 45.67 34.85 10.82 6.05 6.56 0.9144

170-180 174.76 40.20 26.68 13.52 6.44 6.42 0.9948

180-190 185.57 40.57 30.03 10.53 6.11 6.23 0.9703

190-200 195.00 77.77 44.58 33.18 7.25 7.50 0.9591

200-210 205.23 86.47 40.37 46.10 7.99 8.14 0.9757

210-220 214.72 60.43 39.40 21.03 6.99 7.12 0.9762

220-230 224.64 48.83 34.70 14.13 6.46 6.58 0.9745

230-240 234.76 30.42 24.47 5.95 5.85 6.06 0.9641

240-250 245.33 38.62 30.83 7.78 6.16 6.28 0.9767

250-260 254.86 37.67 24.73 12.93 6.78 6.86 0.9760

260-270 264.91 38.37 28.87 9.50 5.96 6.13 0.9617

270-280 274.71 28.95 25.15 3.80 5.32 5.53 0.9538

280-290 284.84 24.10 20.83 3.27 5.19 5.37 0.9545

290-300 295.13 22.90 18.57 4.33 5.47 5.72 0.9428

300-310 305.24 27.72 20.55 7.17 6.18 6.41 0.9472

310-320 314.86 27.10 18.18 8.92 6.60 6.91 0.9403

320-330 325.20 30.85 22.00 8.85 6.02 6.40 0.9204

330-340 334.21 21.78 19.63 2.15 4.42 4.91 0.8845

340-350 344.63 10.30 10.30 0.00 3.85 4.33 0.8867

350-360 351.45 1.67 1.67 0.00 3.59 4.05 0.8767 Table 2 – Site calibration results

A final valid sector of 200-260 & 280-300 degrees, with respect to true North, was determined from site calibration analysis. The combined uncertainties for 6, 10, and 14 m/s were 0.08193, 0.06338, and 0.05353 m/s, respectively.




Figure 3 below plots the wind direction bin ratios that resulted from site calibration at the testing location.

Figure 3 - Site calibration ratio binned data. Valid sector from 200-260 & 280-300 degrees with respect to true North.




SECTION 6.0 TEST EQUIPMENT

Table 3 below shows the test equipment utilized during the Power Performance Test program of the TUGE10. Calibration Certificates can be found in the Appendix.

Measurement Manufacturer Model Serial / Asset Cal Date Cal Due

**Site Calibration

Anemometer Thies Clima 4.3351.00.141 01110057 / 9876 07/26/2013 07/26/2013

**Primary Anemometer

at site calibration Thies Clima 4.3351.00.141 01110056 / 9875 07/26/2013 07/26/2014

Primary Anemometer (original)

Thies Clima 4.3351.00.141 01110056 / 9875 11/16/2017 11/30/2018

Secondary Anemometer (original)

Thies Clima 4.3351.00.141 01110057 / 9876 11/16/2017 11/30/2018

Primary Anemometer (replacement)

Thies Clima 4.3351.00.141 01110058 / 9877 11/26/2018 11/30/2019

Secondary Anemometer (replacement)

Thies Clima 4.3351.00.141 01110059 / 9878 11/26/2018 11/30/2019

Wind Vane (original)

Thies Clima 4.3150.00.141 01110055 / 9879 11/16/2017 11/30/2018

Wind Vane (replacement)

Thies Clima 4.3150.00.141 01110056 / 9880 11/26/2018 11/30/2019

Temperature & Humidity Sensor

Thies Clima 1.1005.54.241 93123 / 9882 11/30/2017 11/30/2018

Barometric Pressure Sensor

LUFFT 8355.03 004.1110.0002.P12

.2.1.00 / 9881 11/24/2017 11/30/2018

Power/frequency Transducer*

Ohio Semitronics

DMT-1042E 10121160 / 31731 11/30/2017 11/30/2018

Current Transformers* Ohio

Semitronics 200:5A

class 0.3

2222500, 2222503, 2355051 / 31732,

31733, 31734 11/30/2017 11/30/2018

Data Acquisition Module

National Instruments

NI 9203 0x168B64D and

0x156943D - -

Loop Calibrator Fluke 707 LOOP CALIBRATOR

31839 2019-01-08 2020-01-31

*PT/CT calibrated as a system **Site calibration performed on a previous project with TUGE at same test location and hub height.

Table 3 – Test equipment and calibrations

A National Instruments cDAQ-9178 backplane and NI-9203 +/- 20 mA 8-channel current module were used for logging the outputs signals from the sensors in Table 2 above. A proprietary LabVIEW program was used to collect and filter data that is stored in raw and 1 Hz data files on the test site computer. Prior to testing, signal verification procedures were carried out on the data acquisition system by Intertek to verify the signals of each transducer against recorded values from the LabVIEW program. Results of that verification are given in Table 4 and 4a below. A similar check was performed to verify the continued accuracy of the overall data acquisition system when the sensors were replaced on December 12, 2018, and similarly no significant error was seen and thus no offset was applied.




Applied values (mA) 4 8 12 16 20

Channels

Wind speed 1 (mA) 3,98-4,03 7,97-8,00 11,96-12,00

15,93-15,99

19,98-20,01

Wind speed 2 (mA) 3,99-4,02 7,99-8,01 11,99-12,01

15,99-16,00

19,97-20,00

Wind direction (mA) 3,98-4,02 7,98-8,01 11,98-12,01

15,98-16,00

19,98-20,00

Current (mA) 3,98-4,02 7,98-8,02 11,97-12,01

15,96-16,00

19,97-20,01

Voltage (mA) 3,97-4,01 7,97-8,01 11,98-12,02

15,97-16,02

19,96-20,00

Frequency (mA) 3,98-4,02 7,98-8,01 11,97-12,01

15,99-16,01

19,96-20,00

Power (mA) 3,97-4,00 7,99-8,03 11,98-12,02

15,98-16,01

19,97-20,01

Temperature (mA) 3,99-4,00 7,99-8,00 11,98-12,01

15,99-16,00

19,97-20,04

Humidity (mA) 3,99-4,00 7,99-8,00 11,98-12,01

15,99-16,00

19,97-20,06

Air pressure (mA) 3,99-4,05 8,0-8,07 11,94-12,01

15,99-16,08

20,00-20,03

Table 4 – Signal verification results

Applied values (mA) 4 8 12 16 20 Channels

Wind speed 1 (mA) 3,99-4,01 7,94-8,01 11,99-12,02 15,94-16,15 19,99-20,05

Wind speed 2 (mA) 3,99-4,07 7,99-8,01 11,99-12,01 15,94-16,01 19,94-20,15

Wind direction (mA) 3,99-4,01 7,98-8,01 11,98-12,02

15,96-16,00

19,96-20,10

Current (mA) 3,98-4,07 7,98-8,05 11,98-12,09 15,98-16,13 19,90-20,14

Voltage (mA) 3,99-4,13 7,96-8,09 11,89-12,14 15,99-16,16 19,99-20,11

Frequency (mA) 3,99-4,16 7,99-8,14 11,97-12,13 15,99-16,12 19,90-20,11

Power (mA) 3,93-4,16 7,99-8,14 11,88-12,05 15,90-16,11 19,88-20,08

Temperature (mA) 4,06-4,24 8,20-8,23 12,20-12,23 16,17-16,20 20,15-20,20

Humidity (mA) 4,22-4,26 8,21-8,23 12,20-12,22 16,17-16,20 20,16-20,17

Air pressure (mA) 4,11-4,13 8,10-8,12 12,08-12,10 16,06-16,08 20,05-20,06

Table 4a – Post-test signal verification results




The data acquisition system is located inside the test data shed. All signals are measured at this location. The data is stored on two separate computers at the Intertek test site, and also stored in the Intertek project file. The power measurement equipment is located inside the control building at an approximate wire run length of 81.5 meters (267.4 feet); which satisfies the required wire run length of greater than 8 rotor diameters, as specified in AWEA 9.1. Figure 4 below displays the arrangement of the meteorological tower with dimensions of instrument locations.

Figure 4 – Meteorological Equipment Tower

The anemometers were calibrated prior to and after the testing was completed. The calibration results were compared and indicated regression lines were within ±0,1 m/s.




SECTION 7.0 TEST PROCEDURE 7.1 DATA COLLECTION The collection of data and measurement procedures were conducted in accordance with the Standards. The data was sampled at a required rate of 1 Hz. The period utilized for all average, maximum, minimum, and standard deviation values was 1 minute, as required by the Standards. No turbine status signal is provided by the turbine controller; therefore, one was not monitored during test. Meteorological data and the turbine output power signals were gathered by the NI 9203 module and stored in daily spreadsheet files on the control building computer. The spreadsheet files are where all analysis according to the Standards was performed. The data was sorted per binning method described in the standard based on 1 minute averaging of the measured, contiguous data.

7.2 DATA REJECTION To ensure that only data obtained during normal operation of the wind turbine was used in the analysis, and to ensure data was not corrupted; selected data sets were excluded from the database under the following circumstances: - External conditions other than wind speed are out of the operating range of the wind turbine, - Turbine cannot operate because of a turbine fault condition, - Turbine is manually shut down or in a test or maintenance operating mode, - Failure or degradation (i.e. due to icing) of test equipment, - Wind direction outside the measurement sector as defined in section 5.2 above, - Wind directions outside valid (complete) site calibration sectors as defined in section 5.2 above, - Reduced power production due to suspected abnormal conditions (i.e. due to icing), - Negative power output values when the wind speeds are well above cut-in (assumed abnormal condition). - Inaccurate wind direction averages due to Northern winds that cross the 360°-0° transition of the wind vane. 7.3 DATA NORMILZATION The 1 minute averaged data sets were normalized to sea-level air density, 1.225 kg/m3. A second normalization to site average air density was not required due to the average air density during test remaining within the specified range of 0.05 kg/m3 of sea-level air density. The calculated site average air density at the Intertek test site for the measurement period was 1.2198 kg/m3. Air density was determined from measured air temperature and air pressure according to Equation 1 from IEC 61400-12-1. Data normalization was then applied to the measured wind speed according to Equation 3 from IEC 61400-12-1. 7.4 DETERMINATION OF RESULTS The measured power curve was determined by applying the “method of bins” to the normalized data sets, using 0.5 m/s bins. Average values for wind speed and normalized power output for each bin was determined according to Equations 4 and 5 from IEC 61400-12-1. Annual energy production was estimated by applying the measured power curve to different reference wind speed frequency distributions. A Rayleigh distribution, which is identical to a Weibull distribution with a shape factor of 2, was used to reflect the wind speed frequency distribution. For determination of AEP, the availability of the wind turbine was assumed to be 100%. AEP estimations were made for hub height annual average wind speeds between 4 and 11 m/s according to Equations 6 and 7 from IEC 61400-12-1. The power coefficient, CP, of the wind turbine was determined from the measured power curve according to Equation 8 from IEC 61400-12-1.




SECTION 8.0 UNCERTAINTY Table 5 below summarizes the Category B uncertainty parameters for the Power Performance measurements. Total Category B uncertainty was obtained by combining each component’s uncertainty using the root-sum squared method. Combined uncertainty is the root-sum-squared combination of Category A and Category B uncertainties of power measurements. Final Category A, Category B, and combined uncertainties are presented in Table 8 in Section 9 of this report. Component Uncertainty Source Power Voltage transducer NA NA Current transformer 0.80% Calibration Power transducer 0.80% Calibration Data acquisition 0.20% Manual Wind Speed Anemometer 0.051 m/s Calibration Operational Characteristics 0.0866 m/s + 0.866 % IEC 61400-12-1 Terrain effects 0.049852 to 0.050673* IEC 61400-12-1 Mounting effects 1.00% Assumption Data acquisition 0.18% Assumption Temperature Temperature sensor 0.25 °C Calibration Radiation shielding 2.0 °C Calibration Mounting effects 0.3249 °C IEC 61400-12-1 Data acquisition 0.09 °C Manual Pressure Pressure sensor 0.29 hPa Calibration Mounting effects 0.1154 hPa IEC 61400-12-1 Data acquisition 0.72 hPa Manual

Table 7 – Uncertainty values used in the analysis *Range of site calibration uncertainties within the valid measurement sector




SECTION 9.0 TEST RESULTS

9.1 DATABASE DESCRIPTION Only a single database was reported for the TUGE10 wind turbine since during testing the TUGE10 turbine was not observed to stop generating power due to cut-out at high wind speeds. 9.2 TABULAR RESULTS Table 8 below shows the normalized and averaged results of the power performance test for the TUGE10 turbine. No normalization to test site average air density is required due to the site average density being within 0.05 kg/m3 of sea-level air density. Table 9 below summarizes the estimation of expected annual energy production (AEP) at sea-level air density.




(m/s) (m/s) (W) (W) (W) (W)0 0.21 -245.50 -558.18 42 - - -

0.5 0.54 -245.32 -31.00 419 7.29 0.92 7.35

1 1.01 -253.96 -4.87 961 2.38 2.14 3.21

1.5 1.52 -249.47 -1.41 1664 1.81 1.32 2.24

2 2.01 -243.45 -0.60 2094 1.38 1.62 2.12

2.5 2.50 -184.61 -0.24 2357 1.18 13.19 13.24

3 3.00 -37.91 -0.03 2541 2.16 32.57 32.64

3.5 3.50 233.57 0.11 2630 4.82 62.15 62.34

4 4.01 699.83 0.22 3158 7.79 108.86 109.14

4.5 4.50 1220.50 0.27 2969 10.32 127.19 127.61

5 5.01 2077.49 0.33 2892 14.06 209.05 209.53

5.5 5.50 3127.43 0.38 3277 16.89 272.96 273.48

6 5.99 4222.67 0.39 2834 15.33 289.34 289.75

6.5 6.50 5284.93 0.38 2747 14.63 284.31 284.69

7 7.00 6204.45 0.36 2861 12.68 261.33 261.64

7.5 7.49 7012.10 0.33 2755 11.30 237.27 237.54

8 7.99 7687.50 0.30 2503 13.02 204.57 204.98

8.5 8.50 8349.19 0.27 2460 9.74 201.61 201.84

9 8.99 8905.39 0.24 2340 9.37 183.04 183.28

9.5 9.49 9326.43 0.22 1959 8.91 143.46 143.73

10 9.99 9503.26 0.19 1837 8.10 69.26 69.73

10.5 10.50 9498.47 0.16 1727 4.80 35.77 36.09

11 10.99 9432.44 0.14 1580 4.00 42.87 43.06

11.5 11.49 9213.67 0.12 1427 6.16 87.71 87.93

12 12.00 8838.21 0.10 1288 11.73 145.39 145.86

12.5 12.49 8405.05 0.09 1227 20.09 175.44 176.59

13 12.99 7974.89 0.07 1177 26.07 176.72 178.63

13.5 13.50 7508.16 0.06 1123 29.75 193.57 195.84

14 13.99 7197.42 0.05 1046 32.70 137.53 141.36

14.5 14.50 6751.43 0.04 915 33.78 196.82 199.70

15 15.00 6376.17 0.04 749 33.64 170.90 174.18

15.5 15.48 6147.06 0.03 572 34.55 112.90 118.07

16 15.98 6102.76 0.03 382 34.71 31.05 46.57

16.5 16.48 6121.81 0.03 247 37.18 24.85 44.72

17 16.97 6163.85 0.03 150 47.42 31.56 56.96

17.5 17.45 6180.25 0.02 105 50.54 24.79 56.30

18 17.98 6261.54 0.02 72 56.31 47.11 73.41

18.5 18.48 6282.85 0.02 40 56.47 26.22 62.27

19 18.97 6315.63 0.02 33 48.59 29.90 57.05

Bin Wind SpeedPower

output

Presentation of data in the measured power curve

Reference air density: 1.225 kg/m^3Category A

Standard

Uncertainty

Category B

Standard

Uncertainty

Combined

Standard

UncertaintyCp

Number of 1-

Minute Data

Sets

Table 8 – TUGE10 performance at sea-level air density




1.225 kg/m^3

25.00 m/s

m/s kWh kWh % kWh

4 15427 4427 28.7 15427 Complete

5 25866 5290 20.5 25867 Complete

6 34991 5534 15.8 35012 Complete

7 41841 5449 13.0 42011 Complete

8 46308 5201 11.2 46950 Complete

9 48659 4875 10.0 50217 Complete

10 49310 4518 9.2 52176 Incomplete

11 48703 4157 8.5 53094 Incomplete

Reference air density:

Cut-out wind speed:

Estimated annual energy production

Standard Uncertainty

Hub height

annual average

wind speed

AEP-MeasuredAEP-

Extrapolated

Complete if AEP-

Measured is at

least 95% of AEP-

Extrapolated

Table 9 – Estimated annual energy production of the TUGE10 at sea-level air density

An indication of “incomplete” in the far-right column of Table 9 does not imply that the database for the test is incomplete. “Incomplete” means that AEP-Measured is not within 95% of AEP-extrapolated. AEP-extrapolated is an estimated extrapolation of annual energy production, where: - AEP-Measured assumes zero power below cut-in wind speed and between the highest valid wind speed bin and cut-out wind speed, and - AEP-Extrapolated assumes zero power below cut-in wind speed and constant power between the highest valid wind speed bin and cut-out wind speed. 9.3 GRAPHICAL RESULTS NOTE: Scatter plots shown in this section (Figures 6, 8, and 9) plot the 60-second average of the non-excluded 1Hz data collected throughout the test period. Figure 5 below shows the graphical results of the power performance test for the TUGE10 turbine. The uncertainty of each wind speed bin is shown as error bars on the graphs. Figure 6 below shows the 1-minute output power values for average, maximum, minimum, and standard deviation of sampled data. Figure 7 below shows the coefficient of performance at sea-level air density. Figure 8 below shows the turbulence intensity as a function of wind speed. The graph shows both sampled data and binned data (average turbulence intensity at given wind speed bin). Figure 9 below displays both average wind speed measured by the primary anemometer and turbulence intensity as a function of wind direction. Figure 10 below displays the comparison between AEP Measured and AEP Extrapolated.




Figure 5 – TUGE10 power curve at sea-level air density; 1.225 kg/m3




Figure 6 - Scatter plot of output power average, maximum, minimum, and standard deviation of 1 Hz data with 60 second averaging

Figure 7 – Coefficient of performance of the TUGE10 with a swept area of 81.71m² at sea-level air density of 1.225 kg/m²




Figure 8 - Wind turbulence intensity as a function of wind speed

Figure 9 - Wind speed and turbulence intensity as a function of wind direction (Database A)




Figure 10 – AEP Measured vs AEP Extrapolated




APPENDIX The following sections can be found within this Appendix:

A Wiring Diagram B Pictures of the Valid Measurement Sector C Calibration Certificates D Revision History




Appendix A – Wiring diagram

Documents

TUGE Energia OÜ POWER PERFORMANCE TEST REPORT · 2019. 5. 20. · POWER PERFORMANCE TEST REPORT TUGE Energia OÜ Intertek Report: 103254243CRT-008 Version: 6-March-2017 Page 6 of