Commissioning Procedure of Turbine and Generator(Rev.0)

3x15MW WAMPU HEPP PROJECT

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Commissioning Procedure of Turbine and Generator

DOCU. NO. : 1000-0183-EM-462-001(1/2)

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2. Set up a three-phase short circuit point at the enclosed busbar short circuit test and disconnect the breaker and disconnecting links at the generator outlet. 3. Disconnect the isolating disconnecting links of the arc-extinguishing coil at the neutral point of the unit. 4. Add a three phase stator ammeter, rotor ammeter and voltmeter beside the excitation panel for the use of monitoring short-circuit current rise of the generator. 5. The secondary side of CT which is not used temporarily within the short circuit range of the generator is reliably short circuited and grounded. 6. Put in unit cooling water system before the unit startup, supply cooling water slightly to the generator air cooler and put in hydraulic machinery protection devices. 7. All generator protections exit, and 8. Test the unit speed with gear disk or tachometer. 4.8.2 Testing procedures 1. Manually start up the unit, to operate the unit until bearing liner temperature of each part is stable. 2. Switch over the excitation device to the manual regulation mode, manually set on the lowest position, put in the separated-excited power source, inspect that there should be current at the secondary side of CT within short circuit range. 3. After the de-excitation switch (FMK) is closed, operate the manual setting to slowly increase the stator current up to 20%, test the current at the secondary side of CT, inspect mutual phase position of the secondary circuit connection and the three phase current balance, check the polarity of each CT and inspect there should be no current at the neutral point of each group of connections. 4. Check the polarity of CT of the excitation transformer and the correctness of its differential protection connection. 5. Gradually increase the stator current up ((approx 75%), recheck the correctness of inspection (4.8.2.3), inspect the setting values of complete and incomplete differential motions of the generator, the mutual phase at the secondary side of the protection CT as loss of excitation, negative sequence overcurrent, overload and etc. and the correctness of connection, inspect the setting values of differential motions of the transformer, inspect the correctness of the current circuits of each measuring and indicating instrument. 6. After completion of the current rise test, reduce magnet and decrease current and trip the de-excitation switch (FMK). 7. Recording of the generator short-circuit characteristics:

3x15MW WAMPU HEPP PROJECT Commissioning Procedure of Turbine and Generator

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DOCU. NO. : 1000-0183-EM-462-001(1/2)

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After the de-excitation switch (FMK) is closed, gradually increase the stator current up to the rated values. During the process of gradual increase of current, read out the three phase stator current and the rotor current at the same time, the classification of current decrease should be above 10 points, draw out the curve of the generator short-circuit characteristics. 8. During the process of test, closel y monitor the operation conditions of the rotor collecting rings and the carbon brushes. 9. When the current of the generator stator reaches the rated value, inspect the output current value at the secondary side of the shaft current protection device. 10. After completion of above-mentioned inspections and tests, trip the de-excitation switch (FMK) under the rated current of the generator and record the de-excitation characteristics of the generator under the rated current. 11. Test that the insulation resistance of the stator windings to the ground, absorption ratio and polarization index should meet the following requirements, if not, measures should be taken to execute arefaction: Insulation resistance (when converted to 100 ℃) R≥____

_U_____= ___10500 ___=7.24 MΩ

（1000 ＋ S ） (1000+

100

450 1

In the formula: R —— Insulation resistance（MΩ）；； U —— Rated voltage of the stator （V）

S —— Rated capacity of the generator （kVA）。 b)

Absorption ratio (when below 40℃) not less than 1.6, polarization index not less than 2.0.

4.8.3 Short-circuit arefaction of the generator 1. Start the units to no-load manually, when the unit operates steadily, put in the separated excitation power source, and close the de-excitation switch of the generator, increase the generator current gradually (at the beginning, the current is controlled below 50% IN.), and the temperature rise is controlled at the scope of 5-80C per hour. During the course of temperature rise, the air temperature through the air cooler of the generator is not higher than 400C and the temperature of stator windings should be controlled between 600C and 650C, but not exceed 800C. 2. During the process of arefaction, when the stator winding current increases to the control value, retaining stage can be entered, the heat preservation lasts approx 8 hours. During this process, the


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temperature can be adjusted with cooling water. 3. After 8 hours heat preservation, current and temperature can be decreased, the temperature dropping rate should be controlled within 10 ℃/h. When the stator winding temperature lowers below 40℃, trip the de-excitation switch to stop the unit. 4. During the process of short circuit arefaction, supply cooling water slightly to the generator air cooler and adjust cold air temperature with cooling water if necessary. 5. After short circuit arefaction, simulate emergency shutdown of the hydraulic machinery and remove the short circuit wire at the short circuit point of the generator. 4.9 Step-up test of the turbine generator unit and adjusting test of the excitation equipment

4.9.1 Conditions provided with the step-up test of the generator 1. Disconnect the breaker and disconnecting links at the generator outlet, close the neutral point isolating switch of the generator. 2. Put in the generator protection and hydraulic machinery protection, temporarily change the overvoltage protection of the generator into 1.3UN, 0.5s. 3. Put in the unit vibration and throw test devices. 4. Switch over the governor and other auxiliary machine control devices to the automatic control mode. 5. The separated-excited mode is still adopted for the unit step-up. Switch over the excitation device to the manual position, the excitation regulator is set on the lowest position. 4.9.2 The generator step-up test 1. Automatically start up with LCU beside the unit the unit, to operate the unit until bearing liner temperature of each part is stable. 2. Put in the separated-excited power source, close the generator de-excitation switch, manually operate the voltage setting to slowly step up as classified as 25%, 50%, 75% and 100%Un which is inspected accordingly. 3. Detection during the unit step-up test 1）Inspect the operation of each live equipment, 2）Inspect that the three phase voltage in the secondary circuit of each potential transformer at the end of the unit should be balanced and the phase sequence correct. Test the voltage output value of PT open-delta, phasing between each PT. 3）Test the voltage of each terminal in the secondary circuit of PT and the correctness of the voltmeter indication, and


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4）When 100%UN, test the generator shaft potential and vibration and throw values of the unit. 4.10 Recording of the no-load characteristics curve of the generator

1）Manually operate the excitation regulator to decrease the generator voltage down to the lowest value. 2）Manually operate the excitation setting to slowly boost the generator voltage and meanwhile read out the values of three phase voltage and the rotor excitation current and the unit frequency. 3）Step by step boost up as of every 10%UN between the range of 10%-60%UN, step by step boost up as of every 5%UN between the range of 60%-100%UN, at least read out two points (UF and IL values) are read out within the range of 100%-120%UN. Boosting is limited in 1.3UN and rated excitation current. Whichever is reached, boosting stops. During the process of boosting, read out the values of stator voltage, rotor current and unit frequenc y at each point at the same time. 4） When boosting to the maximum voltage, quickly return back to the rated value after promptly reading out 5） Manually operate the excitation setting to slowly decrease the generator voltage, meanwhile read out the values of three phase voltage of the stator and the rotor excitation current and the unit frequency at each point. 6） Draw out the no-load characteristics curve of the generator 4.11 Single-phase grounding test of the generator and arc-extinguishing coil position setting:

1）After completion of the generator voltage boosting, reduce magnet and decrease current and trip the de-excitation switch (FMK) to operate the unit in state of no-load (the governor is automatic), 2）Take off the HV fuse of any one phase in the PT cabinet at the end of the unit, one single-phase grounding wire at the lower end in which one grounding ammeter A1 is series-connected and recover the fuse, 3）One compensation ammeter A2 is series-connected between the arc-extinguishing coil grounding wires, 4）Operate the governor to make the unit steadily operates under the rated speed, 5）Disconnect the isolating switch of the generator neutral point arc-extinguishing coil before the de-excitation switch (FMK) is put in, 6）Manually operate the excitation regulator, gradually increase the unit terminal voltage up to 50%UN, read out the single-phase grounding capacitive current (I1) of the generator,


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7）Convert the capacitive current (I1) to the corresponding value (Ic) of the rated voltage, select the gear position of the arc-extinguishing coil and set up according to the principle of under-compensation, 8）After the isolating switch of the arc-extinguishing coil is put in, operate the excitation regulator to increase the unit terminal voltage up to 50% of the rated value, recording grounding current

(I1)

compensated by the arc-extinguishing coil and the current (I2) flowing from the arc-extinguishing coil, start to step down and be de-excited, and 9）In accordance with he setting gear position current (IL) of the arc-extinguishing coil and converted single-phase grounding current (IC) under the rated voltage, calculate the out-of-resonance degree of the arc-extinguishing coil which value should not exceed 20%, 10）During stepping up, inspect the motion of single grounding of the generator (protection outlet is released in advance, only signal given), and 11）Recover normal connections at the unit end and the neutral point after the test is completed. 4.9.3 Regulation and test of the excitation device under no-load of the turbine generator 1. Disconnect the breaker and the isolating disconnecting link at the generat or outlet, 2. Put in the hydraulic machinery protection of the unit, 3.Put in the generator protection, and temporarily set the overvoltage protection at 1.3UN and 0.5s. Put in excitation system protection. 4. Erect test oscillograph and relevant connecting wires beside the excitation device. 5. Recover the excitation device of the generator to permanent self-excitation system. 6. Start up the unit, close the de-excitation switch of the generator and put in excitation device. 7. Manual excitation test Set the voltage setting point in advance, manually start excitation, record excitation wave shape of each passage, overshoot of excitation, swinging times and excitation time respectively. 8. Manually conduct inversion de-excitation test Start excitation to rated voltage, put in inversion de-excitation and record waves, record and read out inversion de-excitation time. 9. Test the voltage regulation range by manual operation: Operate the voltage setting, the terminal voltage of the generator should be able to adjust within the range between 20-110%UN. 10. Inspect that the voltage regulation range of the excitation regulation system should be in conformity with the design requirements, the automatic excitation device should be able to adjust steadily and smoothly within the range between 70-110% of the rated voltage of the generator


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no-load. 11. Manual-automatic passage switchover test of the excitation device: Manual and automatic, two groups of regulator A and B mutually switch over, the unit terminal voltage fluctuation should be ≤5% UN. 12. No-load disturbance test of the excitation: Switch over the excitation device to the automatic mode, add a disturbance (step value) of 10% of the rated excitation voltage onto the regulator voltage setting, inspect the overshoot, swinging times and regulation time during the process of regulation. The disturbance test should be conducted for the regulators A and B respectively. 13. Excitation device frequency characteristics test: Switch over the excitation device to the automatic mode, manually operated the governor to make the unit speed change within the range of ±3HZ, inspect the value of the generator terminal voltage change and record voltage-frequency characteristics curve of the generator. 14. No-load de-excitation test of the excitation system: Trip the de-excitation switch under 50% and 100% of the rated voltage, inspect the condition of de-excitation, record oscillograph diagram and read out the constant of de-excitation time. 15. Operate the unit to automatically stop with the help of LCU after the test is completed.

5. Test of the turbine generator unit with the main transformer and HV distribution equipment 5.1 Short-circuit current rise test

5.1.1 Conditions provided with the short-circuit current rise test: 1. The breaker of the generator, isolating switch, voltage equipment of the generator and relevant HV equipment have all been tested up to standard and provided with the conditions of putting into operation. 2. The main transformer has been tested up to standard and accepted. The oil level and tap switch prove normal. 3. The HV distribution equipment has been tested up to standard and accepted. 4. Decide the current rise path according to the ways of main connection and protection arrangement. 5. The grounding knife of the HV distribution equipment isolating switch at the HV side of the main transformer is used as the three phase short circuit point and practical measures taken to ensure the circuit will not open during current rising process. 6. Set up trip-prevented measures for the breaker and isolating switch in the current rising circuit according to the requirement of current rising.


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7. Put in relay protection and automatic equipment of the generator, the main transformer cooler and the circuit of control signal. 8. The mode of separated excitation is still adopted for excitation. 5.1.2 Testing procedures 1. After automatic startup of the unit is normal, close the de-excitation switch. 2. Manually raise the current to 10% successively, inspect the current at the secondary current circuit of each CT, correctness of the connection and indication of the instrument within the short-circuit range, inspect the current polarity and phase position of the main transformer, busbar and line protection, draw out current vector diagram if necessary. 3. Continue to rise the current up to 50%, 70% and 100% of the generator rated current respectively, inspect and verify the each protection setting value and the correctness of motion, and draw out the current vector diagram of the main transformer, busbar differential protection and line protection. 4. After inspection is completed, reduce magnet and decrease current and trip the de-excitation switch. 5. Operate the unit to automatically stop in the central control room after the test is completed. 5.2 Single-phase grounding test of the main transformer and HV distribution equipment

5.2.1 Set up single-phase grounding point beside the HV side of the main transformer according to the single-phase grounding protection mode. 5.2.2 The neutral point of the main transformer is directly connected to the ground. Successively raise the single-phase grounding current up to the protection motion after the unit starts up, inspect if the motion of the protection circuit is correct and reliable, check up if the motion value is consistent with the setting value. 5.2.3 Remove the single-phase grounding wire after the test is completed and put in single-phase grounding protection. 5.3 Step-up test of the turbine generator unit to the main transformer and the HV distribution

equipment 5.3.1 Put in relay protection device of the generator, main transformer, busbar differential and etc. 5.3.2 The step-up range should include all primary circuit equipment of HV in this stage. 5.3.3 Operate the unit to automatically start in the central control room to make the unit reach to the rated speed. 5.3.4 Manually raise the voltage successively and inspect the operation of the primary circuit equipment under the generator rated voltage value 25%, 50%, 75% and 100%


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5.3.5 Inspect that the secondary voltage circuit, voltage, phase sequence and phase position of the synchronous circuit should be correct.

6. Impact switching in test of the electric power system to the busbar of the HV distribution

equipment and the main transformer 6.1 Preparation and inspection before the test

6.1.1 Bothe the breaker and the isolating switch at the side of the generator have been disconnected. 6.1.2 Decide impact path and breaker at the HV side of the main transformer according to the main connecting mode. 6.1.3 Put in the relay protection of the main transformer and the control, protection and signal of the cooling system. 6.1.4 Put in the neutral point grounding switch of the main transformer. 6.1.5 Putting in, exiting or temporary setting of the line protection are carried out as the system dispatching requirement. 6.1.6 Put in the fault oscillograph equipment. 6.2 Test method

6.2.1 Close the breaker at the HV side of the main transformer, impact switching in is conducted for 5 times totally by utilizing the impact of the s ystem power source to the main transformer 6.2.2 Inspect the operation of the main transformer differential protection and gas protection and record exciting surge oscillogram when the main transformer impacts. 6.2.3 Conduct the impact switching in test of the generator terminal auxiliary transformer for three times and test the secondary voltage frequency sequence at the LV side of the auxiliary transformer 6.2.4 Conduct the service power switchover test by utilizing the system power source to supply the service power. 6.2.5 For the transformers that the rated voltage is 110kV and above, the capacity 15MVA and above, the chromatography test should be conducted for transformer oil before and after impact test.

7. Parallel and load tests of the turbine generator unit 7.1 Parallel test of the turbine generator unit

7.1.1 Inspect the correctness of the simultaneous circuit . 7.1.2 Analogue parallel test: 1． Disconnect the breaker at the simultaneous point and relevant isolating switch,


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2．The system delivers voltage to the line side of the breaker at the simultaneous point, 3． The unit automatically starts to the state of no-load and deliver voltage to the unit side of the breaker at the simultaneous point, 4． Manual and automatic parallel tests are conducted at the simultaneous devices of the LCU of the unit and the LCU of the switch station. 5． Inspect under the automatic mode that the leading time of the switch in signal of the breaker should meet the requirements, inspect the correctness of the simultaneous indicator and meantime record the oscillograms of the generator voltage, system voltage and the breaker switching in pulse. 7.1.3 Formal parallel test 1． After the analogue parallel test is completed, disconnect the breaker at the simultaneous point, decrease voltage of the unit and de-excite. 2．Switch on the isolating switch that was disconnected when the analogue parallel test has been conducting. 3 ． After the unit voltage steps up again, conduct manual and automatic parallel tests at the simultaneous devices of the LCU of the unit and the LCU of the switch s tation. 7.2 On-load test of the turbine generator unit

This test can be conducted after the parallel in test of the unit is completed. Put in the relay protection and the automatic equipment for generator, transformer, HV distribution equipment and line. The operation mode of the switch station is executed in accordance with the dispatching requirement. 7.2.1 Put in automatic subsynchronous device and realize the unit parallel in the grid with the help of the unit outlet breaker. 7.2.2 Manually operate the unit gradually to be loaded as 25%, 50%, 75% and 100%PN, in which operate for one hour at each step. 7.2.3 Inspection and recording during the on-load test of the unit: 1．Record the vibration and throw values at every load of the unit, 2．When the unit load rising up step by step, inspect the load vibration zone of the unit under the water head then, 3．Inspect the noise from relating part of the unit, 4．Record water consuming flow rate under each of the unit l oad, 5. Record the governor opening and

travel of the servomotor, and

6. Record the pressures at the spiral case outlet, the head cover, the inlet and outlet of the draft tube


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and the pressure pulse. 7.2.4 Conduct swift adding and reducing load test of the unit. The unit is made of swift adding and reducing load by means of the power setting of the governor, the variation should not be more than 25% of the rated load. Inspect and record each item under the clause 7.2.3 and observe transition process the unit load variation. During load adding and reducing process, attention should be paid to monitor the variation of the unit vibration and throw. 7.2.5 The governor test under the loading condition of the generator: 1．Select operation parameters of the governor under the loading condition of the generator by means of adjusting test method, 2．Inspect the responsiveness and operation stability of the governor power setting under the loading condition of the generator, and 3．Under the loading condition of the generator, inspect the correctness of the AGC function realized by combination of the local control unit (LCU) and the governor. 7.2.6 Excitation test under the loading condition of the generator: 1．Under the loading condition of the generator, inspect the polarity of the setting-up difference coefficient of the excitation regulator, 2．When the active power is 0%, 50% and 100% of the rated value respectively, adjust the reactive load of the generator to the rated value, 3．Inspect the responsiveness of the reactive setting of the excitation system, 4．Inspect the setting values of maximum and minimum excitation current limits of the excitation system, 5．Inspect the operation capability of the power system stabilizer (PSS), and 6．Under the loading condition of the generator, inspect the correctness of the AVC function realized by combination of the local control unit (LCU) and the excitation equipment. 7.2.7 Quick shutdown test When the unit is 100% loaded, give out the generation-shutdown instruction from the host computer in the central control room to stop the unit quickly. Observe and record each of the following: 1. Record the time needed from the shutdown instruction is given out to the unit fully stops, 2. Observe if the closing process of the governor is normal, 3. Observe if the regulating process and de-excitation of the excitation equipment is normal,


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4. Observe if the brake putting in and releasing is normal, 5. Observe if the generator outlet breaker acts promptly, 6. Observe other electric equipment operate normally, and 7. Observe other parameters as the unit vibration, throw and etc. 7.2.8 Quick startup test After the unit is at fully standstill, give out the shutdown-generation instruction from the host computer in the central control room to start the unit quickly. Observe and record each of the following: 1. Record the time needed from the startup instruction is given out to the unit starts to generate power, 2. Observe if the governor acts normally in the startup process, 3. Observe if the automatic putting in and regulation of the excit ation equipment is normal, 4. Observe if the generator outlet breaker switches in normally, 5. Observe if other electric equipment put in and act normally, and 6. Observe other parameters as the unit vibration, throw and etc. 7.3 Load rejection test of the turbine generator unit

7.3.1 Preparatory works before test 1．Select the PID parameters of the governor to the optimal value defined by no-load disturbance, 2．Adjust the coulomb or non-coulomb monitoring instruments to monitor the unit vibration, throw, spiral case pressure, unit speed (frequency), the servomotor travel and etc., 3．All relay protection and automation devices have been put in, and 4．The parameters of the automatic excitation regulator have been selected at the optimal values. 7.3.2 Load rejection test of the unit 1．The load rejection test of the unit is conducted as four times gradually rejected from 25%, 50%, 75% to 100% (or the maximum load at the water head then) of the rated active power load, 2．Record relevant values as per the chart of load rejection test (as the form in Annex A), 3. Startup of the load rejection test and switching operation to trip the generator outlet breaker are completed at the LCU, 4．When the turbine generator unit suddenly rejects load, inspect stability and overshoot of the automatic excitation regulator. When the turbine generator unit suddenly reject rated active load, the voltage overshoot of the generator should not be more than 15%-20% of the rated voltage, the times


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of oscillating movement not more than 3-5 and regulating time not more than 5s. 5．After the unit suddenly rejects load, dynamic performance of the governor should reach the following requirements: 1）When rejecting 25% of the rated load, inspect the time of immovability of the servomotor should not exceed 0.2s, 2）When rejecting 100% of the rated active load, the wave peak which exceeds 3% of the steady-state speed should not be more than 2 during speed variation, 3）When rejecting 100% of the rated active load, the total time needed should not be more than 40s from that the servomotor moves to the close direction for the first time until the swinging value of the unit speed not more than ±0.5%. 4）When the turbine generator unit rejects load, inspect the dynamic regulating performance of the turbine governing system, check that the emergency closing time of the guide vane servomotor, rates of rise of the water pressure in the spiral case and rate of rise of the unit speed and etc. should be in conformity with the design provisions. If there are any discrepancies, the guide vane closing time or the dual closing inflection point should be readjusted. 7.3.3 Emergency shutdown test After the unit load rejection test completed up to standard, emergency shutdown test can be conducted. In order to lessen damage to the excitation equipment, the emergency shutdown test should be conducted on the condition that the unit is loaded as less as possible. 1. Put in all hydraulic machinery protection and electric accident protection, 2. Operate the unit to automatically start up at the LCU of the unit, and 3. Press down the emergency stop button at the unit LCU and observe each of the following items: 1）

Actions of the governor, excitation equipment, generator outlet breaker and intake

valve of the turbine, 2）

Vibration, throw and noise of the unit, and

3）

Water pressure rise in the penstock.

4. Reset the emergency stop button and release accident of the emergency stop. 7.4 The unit efficiency test

The unit efficiency test is conducted by selecting that the generator operates under the rated load of 25%, 50%, 75% and 100%


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7.4.1 The turbine flow rate is tested with the differential pressure flowmeter provided by the manufacturer. 7.4.2 The working water head of the turbine is tested with differential meter, the turbine working water head is calculated by means of the pressure difference tested between the spiral case inlet and the draft tube outlet 7.4.3 The generator power is tested with the wattmeter provided by the manufacturer. 7.4.4 Via the tested turbine flow rate, the turbine working head and the generator power, 7.5 The maximum output test of the turbine generator unit

7.5.1 In accordance with the procurement and manufacturing contract of the unit, if the condition is provided at the site, the maximum output test of the unit is conducted. 7.5.2 The maximum output test of the unit is conducted at the power factor specified by the contract and the maximum power of the unit, the operating time under the maximum output should lasts not less than 4 hours. Automatically record the temperature rise, vibration, throw, active power and reactive power values, record the servomotor travel and the guide vane opening, check the turbine running characteristic curve and the guaranteed values of the ma nufacturer.

8. Unit operation test of stability and reliability 8.1 Stable and reliable operation for 24 hours

8.1.1 Operation time of stability and reliability is an uninterrupted operation for 24 hours parallel in the power grid. 8.1.2 During the operation, put in all hydraulic machinery protection and electric protection, all the oil, air and water supply system of the unit automatically operate. Record the relevant operation parameters in overall. 8.1.3 The unit operates within 12 load zones from no-load to the maximum load respectively, operate in each load zone for 2 hours, monitor that all equipment operation conditions should meet the requirements of relevant specifications. 8.1.4 During the operation of stability and reliability, there should be no operation interruption caused by faults of the unit, auxiliary equipment of hydraulic machinery and electric equipment. If interruption occurs, the operation of stability and reliability should be conducted again. 8.1.5 In case of interruption which is caused by the fault of the power system or the responsibility of other subcontractors, it can be continued to conduct after the interruption.


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8.2 72 hours on-load trial run test

8.2.1 The unit is parallel in the power system, 72 hours on-load operation is conducted in accordance with the dispatching instruct of the system. 8.2.2 During 72 hours operation, 10 times of manipulation are conducted from the load appointed by the dispatcher to shutdown and from shutdown to the appointed load. 8.2.3 If the unit can not reach the rated output due to not enough working head of the power station or limit of the power system condition, the maximum load on the unit can be confirmed according to the specific conditions of the time, the 72 hours uninterrupted operation is conducted under this load. 8.2.4 Put in all hydraulic machinery protection and electric protection, record the relevant operation parameters in overall as per the operation on duty system. 8.2.5 During 72 hours operation, the operation interruption caused by manufacturing and installation quality of the unit and relevant electromechanical equipment should be inspected and treated up to standard before 72 hours uninterrupted operation starts again. However, the operation time before and after the interruption should not be cumulatively calculated. 8.2.6 After 72 hours uninterrupted test operation, it should stop the unit to overall inspect the electromechanical equipment. Except inspection to the unit, auxiliary equipment and electric equipment, water in the spiral case and the draft tube should be drained out if necessary and the conditions after operation of the water-carrying section o the unit and the hydraulic structure.

9. Joint operation test of multiple units (3 units) 9.1 Load test of joint operation of 3 units

9.1.1 Conduct this test after all test items of the three units have been completed up to standard respectively. 9.1.2 The 3 units successively start up parallel in the power grid. 9.1.3 Inspect and record the items under the clause 7.2.3. 9.1.4 The 3 units are made to operate on different active load and reactive load respecti vely 9.1.5 Conduct a 48 hours operation of stability and reliability and one cycle of start and stop operation 9.1.6 Conduct 4 hours uninterrupted and reliable operation between maximum possible load and no-load, the operation process should not interrupt. 9.2 Simultaneous load rejection test of the 3 units

9.2.1 Preparatory works before test

Commissioning Procedure of Turbine and Generator(Rev.0)

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