SOUTHERN REGIONAL POWER COMMITTEE · PDF fileRGMO/FGMO with MI & MVAR Interchange Meeting held...

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SOUTHERN REGIONAL POWER COMMITTEE BANGALORE

MINUTES OF THE SPECIAL MEETING ON RGMO/MVAR HELD AT SRPC

BENGALURU ON 30th SEPTEMBER 2015

1. INTRODUCTION

A Special Meeting on RGMO performance & MVAR Interchange of SR

Generators was held at Bangalore on 30th September 2015.The list of

participants is at Annexure-I.

Shri S.R. Bhat, Member Secretary, SRPC extended a warm welcome to the

participants to the Special Meeting. He informed that the last Meeting on

RGMO/MVAR had been held in August 2014 and this was the 7th Meeting in

this regard. He said that in the June 2014 Meeting, CERC staff had also

participated and given valuable inputs. Hon’ble CERC had constituted a

Committee to look into various aspects of RGMO/FGMO implementation. He

informed that the 27th TCC/28th SRPC Meetings were scheduled for 9th & 10th

October 2015 and it would be apt to assess the RGMO/MVAR performance in

this Meeting which would enable proper briefing to the higher forum.

It was noted with concern that there was no representation from TNSDLC,

Kaiga GS & UPCL.

2. RGMO/FGMO WITH MANUAL INTERVENTION

It was noted that the following instances had been posted in the web group for

RGMO/FGMO with MI analysis:

MONTH DATE TIME TYPE

Apr-15

07-04-15 21:01 Dip in Frequency

25-04-15 11:41 Rise in Frequency

26-04-15 12:41 Rise in Frequency

May-15 26-05-15 17:55 Rise in Frequency

Jun-15 26-06-15 19:13 Dip in Frequency

Jul-15 28-07-15 11:52 Dip in Frequency

Aug-15 19-08-15 02:33 Dip in Frequency

Sep-15 04-09-15 19:24 Dip in Frequency

RGMO/FGMO with MI & MVAR Interchange Meeting held on 30.09.2015

SRLDC presented the performance of various generators and the presentation is at

Annexure- II. NCTPS, TANGEDCO made a presentation (Annexure- III) on the

status and issues regarding RGMO.

Following was the response of the constituents in each incident.

Instance on 07.04.15

HYDRO THERMAL TOTAL

Possible Actual % Possible Actual % Possible Actual %

AP 15.62 0.67 4.29 154.81 36.64 23.67 170.43 37.31 21.89

TG 0 0 66.7 14.71 22.05 66.7 14.71 22.05

KAR 118.5 34.14 28.81 200.72 11.6 5.78 319.22 45.74 14.33

KER 46.52 36.03 77.45 0 0 46.52 36.03 77.45

TN 14.2 3.02 21.27 201.15 48.27 24 215.35 51.29 23.82

CGS 0 0 260.03 48.02 18.47 260.03 48.02 18.47

SR 194.84 73.86 37.91 883.41 159.24 18.03 1078.25 233.1 21.62


HYDRO THERMAL TOTAL


AP -20.4 -5.14 25.2 -132.73 -15.2 11.45 -153.13 -20.34 13.28

TG -6.63 -3.05 46 -57.33 -29.99 52.31 -63.96 -33.04 51.66

KAR -30.77 -85.24 277.02 -226.64 -11.93 5.26 -257.41 -97.17 37.75

KER -31.97 -54.08 169.16 0 0 -31.97 -54.08 169.16

TN -31.67 -6.44 20.33 -116.69 13.46 -11.53 -148.36 7.02 -4.73

CGS 0 0 -220.96 -32.5 14.71 -220.96 -32.5 14.71

SR -121.44 -153.95 126.77 -754.35 -76.16 10.1 -875.79 -230.11 26.27



HYDRO THERMAL TOTAL


AP -21.21 -12.05 56.81 -129.47 -49.96 38.59 -150.68 -62.01 41.15

TG -13.31 -1.02 7.66 -57.66 -49.49 85.83 -70.97 -50.51 71.17

KAR -41.19 -91.42 221.95 -189.18 1.29 -0.68 -230.37 -90.13 39.12

KER -13.34 -35.4 265.37 0 0 -13.34 -35.4 265.37

TN -22.08 -4.98 22.55 -127.24 -1.96 1.54 -149.32 -6.94 4.65

CGS 0 0 -222.76 -53.11 23.84 -222.76 -53.11 23.84

SR -111.13 -144.87 130.36 -726.31 -153.23 21.1 -837.44 -298.1 35.6


HYDRO THERMAL TOTAL


AP 0 0 122.52 37.33 30.47 122.52 37.33 30.47

TG 0 0 35.25 -4.47 -12.68 35.25 -4.47 -12.68

KAR 78.92 152.52 193.26 149.01 -3.34 -2.24 227.93 149.18 65.45

KER 28.99 24.86 85.75 0 0 28.99 24.86 85.75

TN 15.85 -0.38 -2.4 134.78 21.01 15.59 150.63 20.63 13.7

CGS 0 0 204.65 32.81 16.03 204.65 32.81 16.03

SR 123.76 177 143.02 646.21 83.34 12.9 769.97 260.34 33.81


HYDRO THERMAL TOTAL


AP 16.84 1.34 7.96 110.28 14.75 13.38 127.12 16.09 12.66

TG 0 0 61.2 12.46 20.36 61.2 12.46 20.36

KAR 59.36 51.46 86.69 188.5 18.01 9.55 247.86 69.47 28.03

KER 12.1 0 0 0 0 12.1 0 0

TN 23.53 3.45 14.66 133.51 40.1 30.04 157.04 43.55 27.73

CGS 0 0 225.59 64.6348 28.65 225.59 64.6348 28.65

SR 111.83 56.25 50.3 719.08 149.955 20.85 830.91 206.205 24.82



HYDRO THERMAL TOTAL


AP 5.1 0.68 13.3333 123.92 61.03 49.2495 129.02 61.71 47.83

TG 0 0 55.33 36.26 65.5341 55.33 36.26 65.53

KAR 87.16 1.24 1.42267 91.56 2.72999 2.98164 178.72 3.96999 2.22

KER 9.38 14.41 153.625 0 0 9.38 14.41 153.62

TN -4.08 0.72 -17.647 145.2 6.66 4.58678 141.12 7.38 5.23

ISGS 0 0 336.71 74.0048 21.9788 336.71 74.0048 21.98

SR 97.56 17.05 17.4764 752.72 180.685 24.0043 850.28 197.735 23.26


HYDRO THERMAL TOTAL


AP 11.93 -3.08 -25.817 145.75 36.22 24.8508 157.68 33.14 21.02

TG 0 0 32.04 5.33 16.6355 32.04 5.33 16.64

KAR 61.23 77.3 126.245 139.95 7.48002 5.34478 201.18 84.78 42.14

KER 53.14 9.25 17.4068 0 0 53.14 9.25 17.41

TN 19.69 -0.22 -1.1173 136.7 13.6 9.94879 156.39 13.38 8.56

ISGS 0 0 281.01 33.6948 11.9906 281.01 33.6948 11.99

SR 145.99 83.25 57.0245 735.45 96.3248 13.0974 881.44 179.575 20.37

Summary of Deliberations:

Status of RGMO in new units: On a query NLC informed that RGMO for TS-II Expansion Units was not in

service for both the units due to technical reasons/partial loading. NLC informed that issue would be rectified and RGMO would be put in service within 15 days. SRLDC expressed grave concern that the removal of RGMO had not been intimated.

On a query NTPL informed that RGMO was not in service due to some teething issues and the issues were likely to be rectified before October 2015. RGMO would be put in service before October 2015. SRLDC stated that the generators were taking out RGMO but there was no intimation to SRLDC which was violation of IEGC provisions.

It was noted that TPCIL had committed that they would put the RGMO in service for Unit-I (RGMO was in place for Unit-II) within 15 days and the


committed date was already over. TPCIL stated that they would implement the RGMO logic during the next shut down. SRLDC/SRPC expressed that TPCIL was not putting RGMO though committed which was a matter of serious concern. SRLDC stated that they would direct TPCIL to put RGMO in service else they may be forced not to schedule STOA transactions as the Unit was not meeting the statutory requirements for COD declarations as per CEA/CERC Regulations.

On a query APGENCO informed that RGMO features for the Units of Krishnapatnam JV (SDSPP) had been taken out due to hunting. SRLDC stated that APSLDC was responsible to ensure the Regulatory compliance. SRPC/SRLDC stated that the RGMO needs to be put into service at the earliest.

SRLDC/SRPC expressed concern stating that despite regular follow up the MTPS Stage-III unit was not RGMO compliant. TNSLDC/TANGEDCO were suggested to ensure RGMO availability.

SRLDC/SRPC stated that the Coastal Energen Unit-II, NCC Units, IL&FS Unit-II, Hinduja (APSLDC), Kakatiya (TSSLDC), Singareni (TSSLDC), Bellary Unit-III (KPCL/Kar SLDC), Yeramarus (Kar SLDC), Kudgi (NTPC) etc. should come up with RGMO feature. GENCOs/SLDCs to ensure the compliance.

SRLDC stated that the units had not implemented the RGMO (taken out the RGMO due to some technical reasons etc) and thus not meeting the Regulatory compliance of CEA/CERC Regulations. They could therefore be constrained in restricting scheduling, in case RGMO is not put in place for those units.

RGMO Status point extension to SRLDC/SLDC: SRLDC informed that RGMO status point extension was pending for the

following stations:

IL&FS

NTPL IL&FS informed that RGMO status point was made available to SRLDC

and end to end configuration was to be done. NTPL informed that they were following up with PGCIL in this regard and

status would be extended soon. APSLDC informed that the works regarding status point extension from

Krishnapatnam to SLDC were under progress. SRLDC/SRPC suggested that RGMO status points of state units to be

ensured to respective SLDCs and requested the GENCOs/ SLDCs to follow up.

All the generators would validate the settings of RGMO logic to ensure the compliance of the IEGC Regulations.

All the generators would analyze the response with respect to anticipated and carry out root cause analysis and take corrective action for each and every incident.

Data validation between the state generators and the respective SLDCs and the ISGS generators and SRLDC to be continued.


SRLDC reiterated that DC declaration by generators could be made appropriately to ensure RGMO response. Load Despatch Centers could also schedule appropriately to ensure the response.

It was suggested that the STOAs should not be transacted/permitted by SLDC beyond MCR to ensure that response should be available for grid security. .

Reasons for non performance needed to be qualified with technical justification by the generators.

All technical issues needed to be taken up with OEM to ensure RGMO performance.

APGENCO informed that RGMO was getting triggered at VTPS & RYTPS on multiple instances on daily basis. SRLDC informed that they were analyzing the events through PMU data and there were not many instances which necessitated RGMO triggering. Other constituents also endorsed the SRLDC’s observation. APGENCO was suggested to look into the logic and associated issues.

All the stations should have data logging facility (up to six months) for fruitful analysis/ deliberation.

RGMO should always be in service including at technical minimum.

Intimation on taking out of RGMO needs to be intimated to SRLDC/SLDC along with reasons/revival time.

Parameters would be maintained to ensure RGMO response is available at all instances. .

SLDCs to take proactive role for RGMO implementation/monitoring.

It was noted that individual GENCOs needed to approach through petition to CERC for exemption/extension of RGMO/FGMO compliance.

As per RoP on Petition No.302/MP/2013 all the SLDCs had to furnish the report with details of RGMO/FGMO response of each generating station within their control areas and the details of having taken up the matter with respective SERC in case lack of response or inadequate response from the generating units within their respective states.

SRPC/SRLDC reiterated that SLDCs should take up with their respective State Commissions the lack of response/inadequate response of the generators of their control area.

NTPC stated that the technical difficulties needs to be addressed which would ensure response as mandated in IEGC.

Generators were expected to give response of 5% of the current generation subject to 105% of MCR and analysis was being carried out accordingly.

3.0 MVAR INTERCHANGE

Following are the salient points of the deliberations:

It was noted that Ramagundam STPS, MAPS, NTPL, Kothagudam TPS, Kakatiya TPP, Coastal Energen and UPCL had not furnished the MVAR data despite repeated follow up which was viewed with concern.


It was also noted that Vijayawada TPS, Rayalaseema TPP, Krishnapatnam , NCTPS Stage-II, JSWEL and LKPPL had not furnished the data in specified format.

SRLDC presentation on MVAR absorption with respect capability curve is at Annexure-IV.

Tap Position Recommendations for ISTS connected generators:

Station Unit Present Tap and

Corresponding

Voltage (in kV)

Recommended Tap

and Corresponding

Voltage(in kV)

Remarks

Kaiga I 1 &2 6 & 229.125 7 & 223.25 KGS to change the

tap position as

recommended

Kaiga II 3&4 3 & 409.5 4 & 399 KGS to change the

tap positions as

recommended

NLC TS-II 3

4, 5, 6 &

7

10 & 237

6 & 415

11 & 235

7 & 410

NLC TS-II

Expansion

1 & 2 5 & 400 5 & 400

NTPL 1 & 2 5 & 400 5 & 400

Thermal

Powertech

1 & 2 5 & 420 7 & 399

Coastal

Energen

1 7 & 399 7 & 399

IL & FS 1 420 400

Tap Position Recommendations for intra-state generators:

APGENCO/APSLDC

Station Unit Present Tap

and

Correspondin

g Voltage (in

kV)

Recommended

Tap and

Corresponding

Voltage(in kV)

Remarks

VTS 1 & 2 3, 4, 5 &6

7

11 & 230 13 & 224 5 & 400

13 & 224 13 & 224 5 & 400

APGENCO informed that the tap of Unit-I & II


could not be changed as the units were old.

Rayalseema 1,2,3,4&5 13 & 224 13 & 224

Krishnapatnam JV

1 & 2 6 & 409 400

Upper Sileru 1, 3 & 4 2

7 & 226.6 8 & 228.8

220 220

APGENCO informed that tap for Unit-II could not be changed.

IPPs of AP It is recommended that all IPPS under APSLDC could be advised to change their Tap position corresponding to voltage level of 220 kV.

TSGENCO/TSSLDC


Corresponding

Voltage (in kV)

Recommended Tap

and Corresponding

Voltage(in kV)

Remarks

KTS 2, 3 &4 5, 6, 7&8

9 & 10

11 & 225 13 & 228 12& 225

Suggested to come to 220 kV.

TGGENCO informed that they were planning to replace AVR with DVR and there were some issues in changing the taps

11 5 & 400 5 & 400

Nagarjunsa

gar

1

2,3,4,5,6,

7 & 8

9 & 222

7 & 222

10 & 220

8 & 220

KPCL/Kar SLDC


Corresponding

Voltage (in kV)

Recommended Tap

and Corresponding

Voltage(in kV)

Remarks

Bellary TPS

1 4 & 410 5 & 400 KPCL agreed to change the tap

Raichur TPS

4 5 6 7 8

11 & 409 4 & 410 5 & 420 5 & 410

6 & 409.5

400 400 400 400 400

KPCL agreed to change the taps for the units except unit 6. They would rectify the defects during the planned shut down during October 2015

Kadra PH 7 & 225.5 8 & 222.75


Kodasalli 7 & 225.5 8 & 222.75

Sharavati 9 2 & 231 4 & 220 KPCL informed that tap could not be changed due to technical problems.

UPCL 1 & 2 4 & 409.5 400

JSWEL 1,2, 3 & 4 10 & 412 11 & 400

KSEBL


Corresponding

Voltage (in kV)

Recommended Tap

and Corresponding

Voltage(in kV)

Remarks

Idukki All units 2 & 231 1 & 236.5

Lower Periyar

1

4 & 220

3 & 225.5

Not changed though recommended long back.

Sabarigiri 1,2 & 5 220 225.5 KSEB stated that tap cannot be changed due to technical problems.

TANGEDCO/TNSLDC


Corresponding

Voltage (in kV)

Recommended Tap

and Corresponding

Voltage(in kV)

Remarks

NCTPS

Stage-II

1 9b & 420 13 & 399

Tuticorin TPS

1,2,3,4 & 5

8 & 243

230

Mettur TPS 1,2, 3 & 4 7 & 235.5 7 & 235.5

MTPS St.III 1` TANGEDCO/TNSLDC to confirm

After deliberations following action plan was recommended:

All other stations to ensure their GT Tap positions are optimized so as to bring Grid Voltages to Nominal values.

It was viewed with concern that Kaiga GS had not changed the tap despite regular pursuance and all the adjoining utilities (KPTCL/KPCL) had carried out the recommended modifications.


It was noted that TPCIL and Krishnapatnam units should bring their taps to 400 kV on urgent basis. It was observed that TPCIL units were injecting MVARs (LV side of GT) and as per IEGC 6.6.6 they were to absorb MVAR as per grid requirement. Cumulative effort of all the units in that area (TPCIL, SEL, MEPL, Krishnapatnam and NCCPL) would help in mitigating the high voltage at NPS/Nellore. NCCPL should also come up with its tap at 400 kV.

Bellary, JSWEL and UPCL units should change the tap as per recommendations during first available opportunity and SLDCs should ensure the compliance.

It was noted that many of GT taps had not been changed due to technical constraints and there was no noticeable improvement in this regard. Therefore it was suggested that the GT tap changing issues could be reported as prolonged outage to Hon’ble CERC.

SRLDC could issue messages for Violation of IEGC clause 6.6.6. Messages to state generators would be routed through the respective SLDCs. In cases of no noticeable improvement, the matter could be reported under clause 1.5 of IEGC.

SRLDC pointed out that Srisailam and Nagarjunasagar units were not being put under condenser mode as per directions of SRLDC in certain instances. TSSLDC stated that they were complying with the directions of SRLDC.

SRLDC stared that all new units should come up at nominal grid voltage ( i.e 400 kV, 220 kV etc)

Limiter setting would be as per the capability curve. Any reduced settings needs to be justified technically through OEM.

Respective SLDCs would monitor VAR Interchange of the generators under their control and ensure better voltage profile.

All Generators agreed to take action on the tap changing recommendations. During outages GENCOs/SLDCs would ensure that the recommendations are implemented. Dates of Tap changes and set tap positions should be communicated to SRPC/SRLDC as and when changes are carried out. The same should also be reflected in the information which would be furnished for future analysis

400kV Tap changing is to be carried out only after concurrence of SRLDC.

Number of Generators were not furnishing timely information in correct format. It was suggested that information should be furnished in a timely manner.

Respective SLDCs would participate in reactive power demonstration testing along with the testing team for the units under their control area. Action to be taken on the recommendations finalized in testing report.


Calibration of meters would be undertaken to ensure accurate visibility of the parameters to the plant operators.

Some of the stations AVR voltage control was not going to +/- 5%. It would be examined and rectified.

Stations could undergo themselves reactive demonstration periodically as per the procedure.

It was noted that SEL absorption was getting restricted. SEL agreed to absorb MVAR upto recommended figure of 45 MVAR.

AVR would be kept in constant voltage mode at all the units.

The MVAR data to be posted on [email protected]. Data to be furnished by 5th of each month for the previous month in the web group in the requisite format. Data for state generators to be validated by respective SLDCs. Those who are not members of voltage group need to get in touch with SRLDC to become members.

It was recommended that all the stations should have data logging facility (up to six months) for fruitful analysis/deliberation.

Any, change in capability curves w.r.t. as furnished for MVAR document would be communicated. Wherever, CC is not clear information can be sent in table format also.

MS, SRPC thanked the participants for their active deliberations. He expressed

hope that the generators/SLDCs would take necessary steps on the

recommendations finalized in the meeting. Timely and validated information

was required to be posted on the respective web groups.

*****

mailto:[email protected]

7th RGMO/MVAR Special meeting 30.09.15

RGMO Summary

UNIT SIZE TYPE

INSTALLED

CAPACITY

(MW)

5% OF FULL

GENERATION

(MW)

Considering 80%

AVAILABILITY

(MW)

Considering

80% RESPONSE

(MW)

500MW & ABOVE THERMAL 14860 743 594 476

200MW < IC <

500MW THERMAL 10890 545 436 348

TOTAL THERMAL THERMAL 25750 1287.5 1030 824

40 MW & ABOVE HYDRO 8712 436 348 279

10MW<IC< ABOVE HYDRO 1117.2 56 45 36

TOTAL HYDRO HYDRO 9829 491 393 315

RGMO status point Extension Visibility to SRLDC-CGS

Station Eligible Units

RGMO/FGMO Commissioned

Visibility Not Available

RGMO / FGMO Not

Commissioned

Ramagundam 4,5,6,7 4,5,6,7 -----

Simhadri 3-4 3-4 -----

Talcher ST2* 3,4,5,6 3,4,5,6 -----

NLC2TS II ALL ALL -----

TPCIL 1,2 2 ----- 1

NLC TS I Expn 1&2 1&2 -----

Coastal 1 1 -----

NLC TS II Expn 1&2 1&2 -----

IL&FS 1 1 1

NTPL 1&2 1&2 1&2

Status of RGMO implementation-Status Update

• NLCSTIIEXP UNIT 1&UNIT 2

• TPCIL UNIT 1&2

• SDSTPS UNIT 1&2

• NTPL UNIT 1&2

• COASTAL ENERGEN UNIT 1

• METTUR STAGE 3

RGMO PERFORMANCE OF SOUTHERN REGION ENTITIES

Incidents During last six Months

MONTH DATE TIME TYPE

Apr-15

07-04-15 21:01 DIP in FREQ

25-04-15 11:41 RISE IN FREQ

26-04-15 12:41 RISE IN FREQ

May-15 26-05-15 17:55 RISE in FREQ

Jun-15 26-06-15 19:13 DIP in FREQ

Jul-15 28-07-15 11:52 DIP in FREQ

Aug-15 19-08-15 02:33 DIP in FREQ

Sep-15 04-09-15 19:24 DIP in FREQ

-Max Response is 60% (SCHEDULE REDUCTION AT THAT TIME) -For frequency rise incidents almost reverse response -Overall response is AVERAGE

-30

-20

-10

0

10

20

30

1 2 3 4 5 6 7 8

RGDM U-4

EXP ACT

-40

-20

0

20

40

60

80

1 2 3 4 5 6 7 8

RGDM U-4

%RESPONSE

-No response except for 26th May incident. -Max 47% during 26th May -For all the incidents Generation is less than <500MW(Except for 7th Apr)

-30

-20

-10

0

10

20

30

1 2 3 4 5 6 7 8

RGDM U-5

EXP ACT

-60

-40

-20

0

20

40

60

80

100

1 2 3 4 5 6 7 8

RGDM U-5

%RESPONSE

-For 3 incidents Generation is above 500MW -Maximum response during 26th May -Over all performance is very poor.

-30

-20

-10

0

10

20

30

1 2 3 4 5 6 7 8

RGDM U-6

EXP ACT

-40

-20

0

20

40

60

80

100

120

1 2 3 4 5 6 7 8

RGDM U-6

%RESPONSE

-During rise in frequency(APR) generation was less than 360MW -Maximum response on 26th May-15 -Most of the time generation >= 500MW -Overall response is poor

-30

-20

-10

0

10

20

30

1 2 3 4 5 6 7 8

RGDM U-7

EXP ACT

-30

-20

-10

0

10

20

30

40

50

60

1 2 3 4 5 6 7 8

RGDM U-7

%RESPONSE

-30

-20

-10

0

10

20

30

1 2 3 4 5 6 7 8

SIM UNIT-3

EXP ACT

0

10

20

30

40

50

60

70

80

90

1 2 3 4 5 6 7 8

SIM UNIT-3

%RESPONSE

-Except for 7th Apr incident the response is Good -During all the incidents generation is <500MW -40-80% OF THE EXPECTED RESPONSE

-30

-20

-10

0

10

20

30

1 2 3 4 5 6 7 8

SIM UNIT-4

EXP ACT

-20

0

20

40

60

80

100

1 2 3 4 5 6 7 8

SIM UNIT-4

%RESPONSE

-For rise in frequency some response is there -For dip in frequency the response is poor -All the time generation is <500MW

-30

-20

-10

0

10

20

30

1 2 3 4 5 6 7 8

SIM UNIT-1

EXP ACT

0

20

40

60

80

100

120

1 2 3 4 5 6 7 8

SIM UNIT-1

%RESPONSE

-5 OUT OF 8 INCIDENTS THE RESPONSE IS AVERAGE -For frequency dip incidents yet to improved -All the time generation is less than 500MW

-30

-20

-10

0

10

20

30

1 2 3 4 5 6 7 8

SIM UNIT-2

EXP ACT

0

10

20

30

40

50

60

70

80

90

100

1 2 3 4 5 6 7 8

SIM UNIT-2

%RESPONSE

-5 OUT OF 8 INCIDENTS THE RESPONSE IS AVERAGE -For frequency dip incidents yet to improved -All the time generation is less than 500MW

-20

-15

-10

-5

0

5

10

15

20

25

1 2 3 4 5 6 7 8

VALLUR UNIT-1

EXP ACT

0

20

40

60

80

100

120

1 2 3 4 5 6 7 8

VALLUR UNIT-1

%RESPONSE

-For dip in frequency response is good except for June incident -For rise in frequency no response -Generation during the incidents was < 350MW(During rise in Frequency)

-25

-20

-15

-10

-5

0

5

10

15

20

25

1 2 3 4 5 6 7 8

VALLUR UNIT-2

EXP ACT

-40

-30

-20

-10

0

10

20

30

40

50

60

1 2 3 4 5 6 7 8

VALLUR UNIT-2

%RESPONSE

-The unit was OUT for 4 incidents. -Response is poor for frequency rise incidents -For frequency dip incident response is average.

-15

-10

-5

0

5

10

15

1 2 3 4 5 6 7 8

NLC2 UNIT 1

EXP ACT

-40

-20

0

20

40

60

80

100

120

1 2 3 4 5 6 7 8

NLC2 UNIT 1

%RESPONSE

-FOR ALL THE NLC UNITS: -Reduction in generation for the frequency rise incidents is happening -For dip in frequency almost NIL or Reverse response.

-15

-10

-5

0

5

10

15

1 2 3 4 5 6 7 8

NLC2 UNIT 2

EXP ACT

0

10

20

30

40

50

60

70

80

90

1 2 3 4 5 6 7 8

NLC2 UNIT 2

%RESPONSE

-15

-10

-5

0

5

10

15

1 2 3 4 5 6 7 8

NLC2 UNIT 3

EXP ACT

0

10

20

30

40

50

60

70

80

90

1 2 3 4 5 6 7 8

NLC2 UNIT 3

%RESPONSE

-15

-10

-5

0

5

10

15

1 2 3 4 5 6 7 8

NLC2 UNIT 4

EXP ACT

0

10

20

30

40

50

60

70

80

1 2 3 4 5 6 7 8

NLC2 UNIT 4

%RESPONSE

-15

-10

-5

0

5

10

15

1 2 3 4 5 6 7 8

NLC2 UNIT 5

EXP ACT

0

20

40

60

80

100

120

140

160

1 2 3 4 5 6 7 8

NLC2 UNIT 5

%RESPONSE

-15

-10

-5

0

5

10

15

1 2 3 4 5 6 7 8

NLC2 UNIT 6

EXP ACT

-20

-10

0

10

20

30

40

1 2 3 4 5 6 7 8

NLC2 UNIT 6

%RESPONSE

-15

-10

-5

0

5

10

15

1 2 3 4 5 6 7 8

NLC2 UNIT 7

EXP ACT

-20

-10

0

10

20

30

40

50

60

70

80

1 2 3 4 5 6 7 8

NLC2 UNIT 7

%RESPONSE

-15

-10

-5

0

5

10

15

1 2 3 4 5 6 7 8

NLCEXP1 UNIT 1

EXP ACT

0

10

20

30

40

50

60

70

1 2 3 4 5 6 7 8

NLCEXP1 UNIT 1

%RESPONSE

-15

-10

-5

0

5

10

15

1 2 3 4 5 6 7 8

NLCEXP1 UNIT 2

EXP ACT

0

10

20

30

40

50

60

1 2 3 4 5 6 7 8

NLCEXP1 UNIT 2

%RESPONSE

-30

-20

-10

0

10

20

30

40

1 2 3 4 5 6 7 8

COASTAL UNIT-1

EXP ACT

-60.0

-40.0

-20.0

0.0

20.0

40.0

1 2 3 4 5 6 7 8

% RESPONSE

-Mostly reverse response -For 2 incidents some response is there

-10

-5

0

5

10

15

1 2 3 4 5 6 7 8

TTPS U-1

EXP ACT

-20

-10

0

10

20

30

40

1 2 3 4 5 6 7 8

TTPS U-1

%RESPONSE

-10

-5

0

5

10

15

1 2 3 4 5 6 7 8

TTPS U-2

EXP ACT

-20

0

20

40

60

80

100

120

140

1 2 3 4 5 6 7 8

TTPS U-2

%RESPONSE

-15

-10

-5

0

5

10

15

1 2 3 4 5 6 7 8

TTPS U-3

EXP ACT

-100

-80

-60

-40

-20

0

20

40

1 2 3 4 5 6 7 8

TTPS U-3

%RESPONSE

-10

-5

0

5

10

15

1 2 3 4 5 6 7 8

TTPS U-4

EXP ACT

-10

0

10

20

30

40

50

60

70

80

90

1 2 3 4 5 6 7 8

TTPS U-4

%RESPONSE

-10

-5

0

5

10

15

1 2 3 4 5 6 7 8

TTPS U-5

EXP ACT

-40

-30

-20

-10

0

10

20

30

40

50

1 2 3 4 5 6 7 8

TTPS U-5

%RESPONSE

-10

-5

0

5

10

15

1 2 3 4 5 6 7 8

MTPS U-1

EXP ACT

-40

-30

-20

-10

0

10

20

30

40

1 2 3 4 5 6 7 8

MTPS U-1

%RESPONSE

-15

-10

-5

0

5

10

15

1 2 3 4 5 6 7 8

MTPS U-2

EXP ACT

-60

-40

-20

0

20

40

60

80

1 2 3 4 5 6 7 8

MTPS U-2

%RESPONSE

-15

-10

-5

0

5

10

15

1 2 3 4 5 6 7 8

MTPS U-3

EXP ACT

-80

-60

-40

-20

0

20

40

60

80

100

120

1 2 3 4 5 6 7 8

MTPS U-3

%RESPONSE

-20

-15

-10

-5

0

5

10

15

20

1 2 3 4 5 6 7 8

MTPS U-4

EXP ACT

0

50

100

150

200

250

1 2 3 4 5 6 7 8

MTPS U-4

%RESPONSE

-15

-10

-5

0

5

10

15

1 2 3 4 5 6 7 8

NCTPS U-1

EXP ACT

-30

-20

-10

0

10

20

30

40

1 2 3 4 5 6 7 8

NCTPS U-1

%RESPONSE

-15

-10

-5

0

5

10

15

1 2 3 4 5 6 7 8

NCTPS U-2

EXP ACT

-60

-40

-20

0

20

40

60

80

100

1 2 3 4 5 6 7 8

NCTPS U-2

%RESPONSE

-15

-10

-5

0

5

10

15

1 2 3 4 5 6 7 8

NCTPS U-3

EXP ACT

-100

-80

-60

-40

-20

0

20

40

60

80

100

1 2 3 4 5 6 7 8

NCTPS U-3

%RESPONSE

-10

-8

-6

-4

-2

0

2

4

6

8

10

1 2 3 4 5 6 7 8

VTPS U-1

EXP ACT

-150

-100

-50

0

50

100

1 2 3 4 5 6 7 8

VTPS U-1

%RESPONSE

-10

-8

-6

-4

-2

0

2

4

6

8

10

12

1 2 3 4 5 6 7 8

VTPS U-2

EXP ACT

-20

-10

0

10

20

30

40

50

60

70

80

90

1 2 3 4 5 6 7 8

VTPS U-2

%RESPONSE

-10

-8

-6

-4

-2

0

2

4

6

8

10

12

1 2 3 4 5 6 7 8

VTPS U-3

EXP ACT

-20

0

20

40

60

80

100

1 2 3 4 5 6 7 8

VTPS U-3

%RESPONSE

-10

-8

-6

-4

-2

0

2

4

6

8

10

12

1 2 3 4 5 6 7 8

VTPS U-4

EXP ACT

0

20

40

60

80

100

120

140

1 2 3 4 5 6 7 8

VTPS U-4

%RESPONSE

-10

-5

0

5

10

15

1 2 3 4 5 6 7 8

VTPS U-5

EXP ACT

-40

-20

0

20

40

60

80

100

120

1 2 3 4 5 6 7 8

VTPS U-5

%RESPONSE

-10

-8

-6

-4

-2

0

2

4

6

8

10

12

1 2 3 4 5 6 7 8

VTPS U-6

EXP ACT

-40

-20

0

20

40

60

80

100

120

1 2 3 4 5 6 7 8

VTPS U-6

%RESPONSE

-8

-6

-4

-2

0

2

4

6

8

10

1 2 3 4 5 6 7 8

RYTPS U-1

EXP ACT

-100

-80

-60

-40

-20

0

20

40

60

80

100

1 2 3 4 5 6 7 8

RYTPS U-1

%RESPONSE

-10

-5

0

5

10

15

1 2 3 4 5 6 7 8

RYTPS U-2

EXP ACT

0

10

20

30

40

50

60

70

80

90

1 2 3 4 5 6 7 8

RYTPS U-2

%RESPONSE

-15

-10

-5

0

5

10

15

1 2 3 4 5 6 7 8

RYTPS U-3

EXP ACT

-60

-40

-20

0

20

40

60

80

100

120

140

160

1 2 3 4 5 6 7 8

RYTPS U-3

%RESPONSE

-15

-10

-5

0

5

10

15

1 2 3 4 5 6 7 8

RYTPS U-4

EXP ACT

-60

-40

-20

0

20

40

60

80

100

120

1 2 3 4 5 6 7 8

RYTPS U-4

%RESPONSE

-15

-10

-5

0

5

10

15

1 2 3 4 5 6 7 8

RYTPS U-5

EXP ACT

-100

-50

0

50

100

150

200

1 2 3 4 5 6 7 8

RYTPS U-5

%RESPONSE

-15

-10

-5

0

5

10

15

20

25

30

1 2 3 4 5 6 7 8

KTPS U-11

EXP ACT

-20

0

20

40

60

80

100

120

140

160

1 2 3 4 5 6 7 8

KTPS U-11

%RESPONSE

-30

-20

-10

0

10

20

30

1 2 3 4 5 6 7 8

KTPP U-1

EXP ACT

0

20

40

60

80

100

120

140

1 2 3 4 5 6 7 8

KTPP U-1

%RESPONSE

-15

-10

-5

0

5

10

15

1 2 3 4 5 6 7 8

RTPS U-1

EXP ACT

-50

0

50

100

150

200

250

300

1 2 3 4 5 6 7 8

RTPS U-1

%RESPONSE

-10

-8

-6

-4

-2

0

2

4

6

8

10

1 2 3 4 5 6 7 8

RTPS U-2

EXP ACT

-60

-50

-40

-30

-20

-10

0

10

20

1 2 3 4 5 6 7 8

RTPS U-2

%RESPONSE

-15

-10

-5

0

5

10

15

1 2 3 4 5 6 7 8

RTPS U-3

EXP ACT

-5

-4

-3

-2

-1

0

1

2

3

4

1 2 3 4 5 6 7 8

RTPS U-3

%RESPONSE

-15

-10

-5

0

5

10

15

1 2 3 4 5 6 7 8

RTPS U-4

EXP ACT

-6

-4

-2

0

2

4

6

8

1 2 3 4 5 6 7 8

RTPS U-4

%RESPONSE

-15

-10

-5

0

5

10

15

1 2 3 4 5 6 7 8

RTPS U-5

EXP ACT

-10

-5

0

5

10

15

20

25

30

35

1 2 3 4 5 6 7 8

RTPS U-5

%RESPONSE

-15

-10

-5

0

5

10

15

1 2 3 4 5 6 7 8

RTPS U-6

EXP ACT

-10

0

10

20

30

40

50

60

70

80

1 2 3 4 5 6 7 8

RTPS U-6

%RESPONSE

-15

-10

-5

0

5

10

15

1 2 3 4 5 6 7 8

RTPS U-7

EXP ACT

-100

-80

-60

-40

-20

0

20

40

60

1 2 3 4 5 6 7 8

RTPS U-7

%RESPONSE

-15

-10

-5

0

5

10

15

20

1 2 3 4 5 6 7 8

RTPS U-8

EXP ACT

-250

-200

-150

-100

-50

0

50

100

1 2 3 4 5 6 7 8

RTPS U-8

%RESPONSE

-200

-150

-100

-50

0

50

100

150

200

1 2 3 4 5 6 7 8

TOTAL AP

EXP ACT

0

5

10

15

20

25

30

35

40

45

1 2 3 4 5 6 7 8

TOTAL AP

%RESPONSE

-80

-60

-40

-20

0

20

40

60

80

1 2 3 4 5 6 7 8

TOTAL TELANGANA

EXP ACT

-20

0

20

40

60

80

100

1 2 3 4 5 6 7 8

TOTAL TELANGANA

%RESPONSE

-300

-200

-100

0

100

200

300

400

1 2 3 4 5 6 7 8

TOTAL KARNATAKA

EXP ACT

-10

0

10

20

30

40

50

60

70

1 2 3 4 5 6 7 8

TOTAL KARNATAKA

%RESPONSE

-120

-100

-80

-60

-40

-20

0

20

40

60

80

1 2 3 4 5 6 7 8

TOTAL KERALA

EXP ACT

0

50

100

150

200

250

300

350

1 2 3 4 5 6 7 8

TOTAL KERALA

%RESPONSE

-200

-150

-100

-50

0

50

100

150

200

250

1 2 3 4 5 6 7 8

TOTAL TN

EXP ACT

-10

-5

0

5

10

15

20

25

30

35

1 2 3 4 5 6 7 8

TOTAL TN

%RESPONSE

-300

-200

-100

0

100

200

300

400

1 2 3 4 5 6 7 8

TOTAL CGS

EXP ACT

-10

0

10

20

30

40

50

1 2 3 4 5 6 7 8

TOTAL CGS

%RESPONSE

-1000

-500

0

500

1000

1500

1 2 3 4 5 6 7 8

TOTAL SR

EXP ACT

0

10

20

30

40

50

60

1 2 3 4 5 6 7 8

TOTAL SR

%RESPONSE

RGMO PETITION BY NLDC

• Record of Proceedings

• KARNATAKA RESPONSE FOR 14.01.15 INCIDENT

RGMO PET.pdf

6.RGMO ANALYSIS FOR 14-01-2015_1921.xls

6.RGMO ANALYSIS FOR 14-01-2015_1921.xls

Emphasis in IEGC

4.6.1(b)Reactive Power Compensation

The person already connected to the grid shall also provide additional reactive compensation as per the quantum and time frame decided by respective RPC in consultation with RLDC. The Users and STUs shall provide information to RPC and RLDC regarding the installation and healthiness of the reactive compensation equipment on regular basis. RPC shall regularly monitor the status in this regard

Emphasis in IEGC

6.6.6 Reactive Power and Voltage Control

The ISGS and other generating stations connected to regional grid shall generate/absorb reactive power as per instructions of RLDC, within capability limits of the respective generating units, that is without sacrificing on the active generation required at that time. No payments shall be made to the generating companies for such VAr generation/absorption

Observations

• Observations made on the basis of details submitted by generating stations.

• Input details submitted for past 3 months

- June-15,July-15,Aug-15

MVAR file

Masterfile.xls

Observations

• TTPS

Tap position can be brought to 12(230kV) from 8(243kV) as voltage variation is 243-220kV

Mostly injecting to Grid

• BTPS

Tap position can be brought to 5(400kV) from 4(410kV)

Voltage variation- 420-399kV

Observations

• RTPS

Even though tap kept at 224kV, MVAR is being injected at 231kV for U#1 and U#2

Tap position for U#4,U#7,U#8 can be brought to 400kV

Tap position for U#6 kept at 400kV, only injection is observed

KPCL may clarify correct tap position

Observations

• NCTPS St 1

Voltage is less than 230kV; mostly injecting

• MEPL & SEL

Operating at higher LV reference leading to lesser absorption

Observations

• Vallur

All units are injecting at 400-410kV voltages even though the tap kept at 400kV

• Sharavathy

Except U#9(at 230kV) all other units kept at 220kV

Observations

• NLC II

Tap position of units connected at 220kV level.

Tap position specified is different in same file

Tap can be brought to 400kV level

• NLC I

Tap position can be kept at same voltage level.

Observations

• VTPS

Confirmation of tap status of U#3,4,5,6

• NCTPS St2

U#1Tap position to be changed to 400kV

• Kaiga

Tap position not specified

Observations

• TPCIL

Tap position to be brought to 400kV

• SDS,Krishnapatnam

Minimum Excitation Limit - Explanation

Observations

• Performing as per Capability curve

Simhadri , NLC I Expn, RTPP

• Analysis not done for following due to less/no generation

Recommendations of MVAR testing

VTPS

• Unit 1 to 6 – Change in tap position was recommended

- Not mentioned tap position in the submitted data

• Unit 7 – Absorption level increased as recommended


Kadra

• Tap position suggested No.8 (222.75kV)

• Present tap of all units at 7(225.5kV)

Kodasalli

• Review of AVR setting recommended

• Taps of all units may be brought to 8 (222.75kV)


Simhadri

• Difference in load angle limiter operation

MEPL & SEL

• Operating at higher LV reference leading to lesser absorption


MTPS

• Tap position at 235.75 kV (No.7) for 3 units & one unit at 230kV

• Tap position of all units to be set at same voltage so as to avoid circulating current

Details Submitted

Data Not Submitted

Ramagundam - All units

MAPS

Talcher Stg II

NTPL

Coastal Energen

KTPS

Kakatiya TPS

Data Not in Format

• VTPS

• RTPP

• Lanco

• NCTPS St2

• Jindal

• SDS,Krishnapatnam

Unknown is Ocean

Known is Drop

TANGEDCO & The constituents of Southern Region

sincerely thanked

Hon’ble CERC,

The Respected Chairman, Committee on FGMO,

All the Respected Members,

The Respected Convener

For having given the oppurtunity in the process of

for fine tuning the FGMO/RGMO performance of our

Generating units to serve to our Country

NCTPS, TANGEDCO

Committee held 3 meetings at CERC; first meeting was

held on 03.11.2014, second meeting was held on

21.11.2014 and the third meeting was held on 16.03.2015.

750 MW

The TOR of the Committee reads as below:

(i)To look into the problems of generating units

in implementing RGMO/FGMO

(ii) To suggest measures for implementation of

FGMO with suitable modifications /

amendments in CERC Regulations / IEGC

(iii) Any other recommendations to facilitate

FGMO operation

NCTPS, TANGEDCO

750 MW

NCTPS, TANGEDCO

TANGEDCO thank

The Member Secretary, SRPC

SRLDC, POSOCO and The Constiuents

For having given the opportunity to

share the experience on RGMO to

the constituents of Southern Region

750 MW

NCTPS, TANGEDCO

Date RGMO Expected Actual RGMO

Response % Achieved

Frequency dip

07 04 2015 883.41 159.24 18.03

26.06.2015 638.69 23.52 3.68

28.07.2015 714.34 118.45 16.58

19.08.2015 750.48 157.32 20.96

04.09.2015 725.72 148.154 20.41

Frequency raise

25.04.2015 -754.35 -76.16 10.1

26.04.2015 -726.31 -153.23 21.1

26.05.2015 -822.89 -237.81 28.9

For the period from Apr 2015 to Sep 2015

Courtesy: SRLDC

750 MW

8 MW from NCTPS Unit 3 for 26.06.2015

883.4

638.7714.3 750.5 725.7

159.2

23.5118.5 157.3 148.2

0.0

200.0

400.0

600.0

800.0

1000.0

1 2 3 4 5

MW

Incident

RGMO Target Vs Actual by Southern Region, India -Frequency Dip during Apr - Sep 2015

RGMO Target RGMO Actual

NCTPS, TANGEDCO

Courtesy: SRLDC

750 MW

NCTPS, TANGEDCO

RGMO Target Vs Actual by Southern Region, India -

Frequency raise during Apr - Sep 2015

-754.4 -726.3

-822.9

-76.2-153.2

-237.8

-900.0

-800.0

-700.0

-600.0

-500.0

-400.0

-300.0

-200.0

-100.0

0.0

1 2 3

Incident

MW

RGMO Target RGMO Actual Courtesy: SRLDC

750 MW

NCTPS, TANGEDCO


Response % Achieved

Frequency dip

07 04 2015 883.41 159.24 18.03

26.06.2015 638.69 23.52 3.68

28.07.2015 714.34 118.45 16.58

19.08.2015 750.48 157.32 20.96

04.09.2015 725.72 148.154 20.41

Frequency raise

25.04.2015 -754.35 -76.16 10.1

26.04.2015 -726.31 -153.23 21.1

26.05.2015 -822.89 -237.81 28.9


Courtesy: SRLDC

750 MW

NCTPS, TANGEDCO

Date MCR of Machines

on Bar Calculated RGMO

5% of MCR RGMO Expected by

SRPC 5% MCR Actual RGMO

response

Frequency dip incidents

2-Sep-13 20069 1003.45 1003 -9

3-Sep-13 19709 985.45 985 160

5-Sep-13 19977 998.85 999 29

7-Sep-13 20272 1013.6 1014 -178

10-Sep-13 17719 885.95 886 276

12-Sep-13 20553 1027.65 1028 61

13-Sep-13 19935 996.75 997 69

19-Sep-13 22495 1124.75 1125 -25

21-Sep-13 22070 1103.5 1104 359

25-Sep-13 21977 1098.85 1099 3

Frequency raise incidents :

1-Sep-13 20223 -1011.15 -1011 146

6-Sep-13 19555 -977.75 -978 21

10-Sep-13 17719 -885.95 -602 -62

13-Sep-13 19208 -960.4 -959 -128

14-Sep-13 19716 -985.8 -984 -36

16-Sep-13 22529 -1126.45 -1125 -221

19-Sep-13 20097 -1004.85 -1003 -222

Courtesy: SRLDC

750 MW

NCTPS, TANGEDCO

1003 985 999 1014

886

1028 997

1125 1104 1099

-9

160

29

-178

276

61 69

-25

359

3

-400

-200

0

200

400

600

800

1000

1200

1 2 3 4 5 6 7 8 9 10

MW

Incidents

RGMO target Vs Achieved by Southern Region, India

RGMO target RGMO response Courtesy: SRLDC

On 02 Mar 2015 incident, SR response was 159 * MW as against the thermal target of 744 MW

No of incidents no negative direction 1000 MW

Sep 2013

750 MW

NCTPS, TANGEDCO

Reverse response 07.04.2015

Station Unit IC in MW Rgmo Status

StartGen EndGen First/

Second Response

Simhadri Stage1

2 500 RGMO 476.29 474.26 -2.03

Neyveli TS II

5 210 RGMO 220.31 219.48 -0.83

Neyveli TS II

7 210 RGMO 218.38 217.54 -0.84

Jindal 3 300 RGMO 299.32 298.18 -1.14

Raichur TPS

3 210 RGMO 198.73 198.35 -0.38

Raichur TPS

8 250 RGMO 181.99 181.54 -0.45

UPCL 1 600 RGMO 496.96 493.54 -3.42

Total -9.09

RGMO Target Vs Actual by Southern region, India -

Ferquency dip

Apr to Sep 2015

883.4

638.7714.3 750.5 725.7

159.2

23.5118.5 157.3 148.2

0.0

200.0

400.0

600.0

800.0

1000.0

1 2 3 4 5

Incident

MW

RGMO Target RGMO Series

NCTPS, TANGEDCO

Courtesy: SRLDC

750 MW

NCTPS, TANGEDCO

RGMO Target Vs Actual by Southern Region, India Frequency raise during

Apr - Sep 2015

-754.4 -726.3-822.9

-76.2-153.2

-237.8

-1000.0

-800.0

-600.0

-400.0

-200.0

0.01 2 3

Incident

MW

RGMO Target RGMO ActutalCourtesy: SRLDC

750 MW

NCTPS, TANGEDCO

1003 985 999 1014

886

1028 997

1125 1104 1099

-9

160

29

-178

276

61 69-25

359

3

-400

-200

0

200

400

600

800

1000

1200

1 2 3 4 5 6 7 8 9 10

MW

Incidents

RGMO Expected Vs Response Frequency dip

Expected RGMO MW Actual RGMO Response MW Courtesy: SRLDC

On 02 Mar 2015 incident, SR response was 159 * MW as against the target of 744 MW

Response around 0 MW

Target around 1000 MW

Southern Region, India

Sep 2013

750 MW

NCTPS, TANGEDCO

-1011 -978

-602

-959 -984

-1125-1003

14621

-62-128

-36

-221 -222

-1200

-1000

-800

-600

-400

-200

0

200

400

1 2 3 4 5 6 7

MW

Incidents

RGMO Expected Vs Response Frequency rise


Target around -1000 MW



Sep 2013

750 MW

NCTPS, TANGEDCO

Required RGMO Performance or MW output

Consistency among Units of a station

for a single RGMO incident

Consistency of station for several RGMO incidents

Sustainability for 2 – 3 minutes

System demand that for narrowing down the gap between the target & response

Sustainability for 2 – 3 minutes by all the Units

is the ultimate target and the result by RGMO will

have to be analysed by the Power System Engineers. ???

Consistency of a single Unit for

several RGMO incidents

750 MW

NCTPS, TANGEDCO

Performance of NTECL, Tamilnadu, SR

Unit # MCR of

Machines on Bar

5% of MCR

Current generati

on

RGMO Expected 5%

current generation

Actual RGMO

response

% achieveme

nt

I 500 25 339 16.95 16 94.4

II 500 25 356 17.80 16 89.89

III 500 S/D -- -- -- --

KWU turbines EHG System - RGMO

Date of incident : 02 Mar 2015 49.98 Hz to 49.78 Hz

34.75 32 92.08% Station

JV of NTPC & TNEB

Courtesy: SRLDC

750 MW

NCTPS, TANGEDCO

Sl. No

Name of Thermal Station

Unit No.

MW Capa- city

Generation at the instant

Governor Mode

From

(MW) To

(MW) Pickup

(MW) Remarks if any

Incident 1 : 01.11.2014 02:20 to 02:21 Hrs 50.00 Hz to 49.88 Hz

1

North Chennai Thermal Power Station

I 210

157 RGMO 157

168 11 26 MW raise has

been pumped into the grid with 5.06% increase at the instant generation level.

2 II 210

201 RGMO 201

209 8

3 III 210

153 RGMO 153

160 7


1 North

Chennai Thermal Power Station

I 210

170 RGMO

170 167 3 15 MW fall with

2.78% decrease at the instant generation level has been performed.

2 II 210

200 RGMO 200

190 10

3 III 210

169 RGMO 169 167 2


1


I 210 194 RGMO 194 205 11 28 MW raise has

been pumped into the grid with 4.71% increase at the instant generation level.

2 II 210 204 RGMO 204 211 7

3 III 210 197 RGMO 197 207 10

RGMO response of North Chennai Thermal PS 3 x 210 MW Units TNAGEDCO, SR

750 MW

NCTPS, TANGEDCO

Sl. No

Name of Thermal Station

Unit No.

MW Capa- city

Generation at the instant

Governor

Mode

From

(MW) To

(MW)

Pickup

(MW) Remarks if any


1 North Chennai Thermal Power Station

I 210 210 RGMO 210 199 11 24 MW fall with 4.26%

decrease at the instant generation level has been performed.

2 II 210 208 RGMO 208 195 13

3 III 210 145 RGMO 145 145 0


1


I 210

S/D RGMO

--

-- -- 10 MW raise has been

pumped into the grid with 2.72% increase at the instant generation level. Unit 2 - Frequency dip for RGMO not captured due to elevated f measurement. Unit 3 Inspite of process requirement for fall in MW from 198 to 194 MW just before RGMO instance, RGMO lifted this unit level to 204 MW (5.15%)

2 II 210

173 RGMO

173 173 0

3 III 210

194 RGMO

194 204 10


1


I 210 213

RGMO 213 214 1 17 MW raise has been pumped

into the grid with 2.68% increase at the instant generation level. Unit 1 – Due to reduced Pressure and load limiter. The operators instructed to keep the load limiter considering RGMO demand.

2 II 210 213

RGMO 213 220 7

3 III 210

209 RGMO

209 218 9

12/17 Incidents

750 MW

NCTPS, TANGEDCO

Performance of North Chennai Thermal Power Station, TANGEDCO, SR

Date MCR of

Machines on Bar

5% of MCR

Current generati

on

RGMO Expected 5%

current generation

Actual RGMO

response

% achievemen

t Remarks

01.11.2014 630 31.5 511 25.6 26 101.76

05.11.2014 630 31.5 539 19.4 15 77.30 Fall of frequency is 0.09 Hz only and target corrected.

23.11.2014 630 31.5 595 29.8 28 94.12

16.12.2014 630 31.5 418 20.9 24 114.83

14.01.2015 630 31.5 377 18.9 10 53.05 Elevated f measurement & corrected.

02.03.2015 630 31.5 635 31.5 17 53.97 Load limiter problem and operators were advised


Average 82.51%

750 MW

NCTPS, TANGEDCO

Performance of Unit 3, NCTPS, TANGEDCO

for period from Apr 2015 to Sep 2015

750 MW

Unit 3 NCTPS, TANGEDCO

Date Start MW End MW Target Actual

1 04-Jul-15 212 223 04-Jul-15 10.5 11

2 25-Apr-15 0 0 25-Apr-15 0 0

3 26-Apr-15 0 0 26-Apr-15 0 0

4 26-May-15 214 200 26-May-15 10.5 14

5 26-Jun-15 207 215 26-Jun-15 10.3 8

6 28-Jul-15 212 216 28-Jul-15 10.5 4

7 19-Aug-15 211 216 19-Aug-15 10.5 5

8 04-Sep-15 0 0 04-Sep-15 0 0

1 04-May-15 204 214 04-May-15 10.2 10

2 22-Apr-15 210 192 22-Apr-15 10.5 18

3 24-May-15 174 190 24-May-15 8.7 16

4 27-Apr-15 208 214 27-Apr-15 10.4 6

52.3 42 80.31%

NCTPS, TANGEDCO

Performance of Unit 3, NCTPS, TANGEDCO

for period from Apr 2015 to Sep 2015

750 MW

Incidents 6 & 7 Load limiter problem – Operators advised please.

NCTPS, TANGEDCO

Performance of Mettur Thermal Power Station, TANGEDCO, SR

Date MCR of

Machines on Bar

5% of MCR

Current generation

RGMO Expected 5% current generation

Actual RGMO

response

% achievement

16.12.2014 840 42 824 41.2 18 43.69

14.01.2015 630 31.5 607 30.35 13 42.84

02.03.2015 840 42 804 40.2 23 57.14

LMZ turbines FGMO with MI

Manual intervention – dictates consistency

Alarming for the occurrence of RGMO incident

based on ripple factor is given to activate unit operators

for the manual intervention

750 MW

NCTPS, TANGEDCO

Performance of Simhadri Thermal Power Station, NTPC, SR

Unit # MCR of

Machines on Bar

5% of MCR

Current generati

on

RGMO Expected 5%

current generation

Actual RGMO

response

% achieveme

nt

I 500 25 428 21.4 18.1 84.6

II 500 25 401 20.1 13.3 66.3

III 500 25 501 25.1 7.7 30.7

IV 500 25 496 24.8 5.2 21.0

Date of incident : 02 Mar 2015

70 44.3 62.3% Station

NTECL 32 MW NCTPS 17 MW

Total this three stations 93 MW for 159 * MW

MTPS 23 MW through MI & Total by 4 stations 116 MW

Courtesy: SRLDC

66 Thermal units on Bar for the

02 Mar 2015 incident

as reported by SRLDC

750 MW

NCTPS, TANGEDCO

NCTPS Responses - 3 x 210 MW Units 1 Nov 2014

150

160

170

180

190

200

210

2:18:18

2:18:33

2:18:48

2:19:03

2:19:18

2:19:33

2:19:48

2:20:03

2:20:18

2:20:33

2:20:48

2:21:03

2:21:18

2:21:33

2:21:48

2:22:03

2:22:18

2:22:33

2:22:48

2:23:03

2:23:18

2:23:33

2:23:48

2:24:03

2:24:18

2:24:33

2:24:48

2:25:03

2:25:18

2:25:33

2:25:48

2:26:03

2:26:18

2:26:33

Time

MW

Unit 1 Unit 2 Unit 3


165

170

175

180

185

190

195

200

205

10:28:18

10:28:36

10:28:54

10:29:12

10:29:30

10:29:48

10:30:06

10:30:24

10:30:42

10:31:00

10:31:18

10:31:36

10:31:54

10:32:12

10:32:30

10:32:48

10:33:06

10:33:24

10:33:42

10:34:00

10:34:18

10:34:36

10:34:54

10:35:12

10:35:30

10:35:48

10:36:06

10:36:24

Time

MW



170

175

180

185

190

195

200

205

210

215

220

12:1

5:4

8

12:1

6:0

9

12:1

6:3

0

12:1

6:5

1

12:1

7:1

2

12:1

7:3

3

12:1

7:5

4

12:1

8:1

5

12:1

8:3

6

12:1

8:5

7

12:1

9:1

8

12:1

9:3

9

12:2

0:0

0

12:2

0:2

1

12:2

0:4

2

12:2

1:0

3

12:2

1:2

4

12:2

1:4

5

12:2

2:0

6

12:2

2:2

7

12:2

2:4

8

12:2

3:0

9

12:2

3:3

0

12:2

3:5

1

12:2

4:1

2

12:2

4:3

3

12:2

4:5

4

12:2

5:1

5

12:2

5:3

6

Time

MW


NCTPS Responses - 3 x 210 MW Units 16 Dec 2014 (Unit 3 TM 140 MW)

192

194

196

198

200

202

204

206

208

210

212

10:02:46

10:02:58

10:03:10

10:03:22

10:03:34

10:03:46

10:03:58

10:04:10

10:04:22

10:04:34

10:04:46

10:04:58

10:05:10

10:05:22

10:05:34

10:05:46

10:05:58

10:06:10

10:06:22

10:06:34

10:06:46

10:06:58

10:07:10

10:07:22

10:07:34

10:07:46

10:07:58

10:08:10

10:08:22

10:08:34

10:08:46

10:08:58

Unit 1 Unit 2

26 MW

/25.6

15 MW /19.4

28 MW /29.8

24 MW /20.9

Expected from 3 x 210 MW Units = 31.5 MW at full load 750 MW

NCTPS, TANGEDCO






& again consistency







750 MW

NCTPS, TANGEDCO

From Nov 2014 to Mar 2015

Not capturing at higher frequency

Elevated f measurement

Load limiter

Lower target Lower target

750 MW

NCTPS, TANGEDCO

RGMO Target Vs RGMO response of NCTPS, TANGEDCO, SR

25.6

19.4

29.8

20.918.9

31.5

26

15

28

24

10

17

0

4

8

12

16

20

24

28

32

1 2 3 4 5 6

Incidents

MW

RGMO Target RGMO Response

For Sixth incident, SR response was 159*MW (21.37%) as against the target of 744MW

NCTPS share of 17 MW & TANGEDCO achieved 38 MW

750 MW


Ferquency dip

Apr to Sep 2015

883.4

638.7714.3 750.5 725.7

159.2

23.5118.5 157.3 148.2

0.0

200.0

400.0

600.0

800.0

1000.0

1 2 3 4 5

Incident

MW


NCTPS, TANGEDCO

Courtesy: SRLDC

750 MW

Multiple Controllers

Multiple OEMs

Multiple Generating units

Multiple Sizes/capacities

Multiple Outputs

Multiple Process activities

Multiple Unit operators

Multiple Process parameters for + commercial terms

Unique Goal of RGMO

with desired MW on our grid NCTPS, TANGEDCO

Southern Region

66 Thermal units on Bar for the 02 Mar 2015 incident

as reported by SRLDC

43 MW by 53 machines

We lag, the reason is

Technically Workable

NTECL 2 32 MW

SIMHADRI 4 44 MW

NCTPS 3 17 MW

MTPS 4 23 MW MI

Total by 4 stations 116 MW

Total response 159 MW

Balance - 53 machines 43 MW

750 MW

RGMO Guidelines – CEA

Implementation – Generating Units, OEMs

Incidents identification – RGMO Software block, GU & SRLDC

Operating Limits & TG response - Generating Units

Continued process response - Generating Units

Or Secondary Control

Collection of data from History - Generating Units & SRLDC

Analysis - Generating Units & SRLDC

Identification of Corrections - Generating Units

RGMO

Performance

OK

Not OK

10% error in each activity, successful rate will be (0.9)7 = 0.4783


TG response

100% Responsibility

with GU only

NCTPS, TANGEDCO

750 MW

Date of incident : 02 Mar 2015 Unit 7 of ABCDEF station

NCTPS, TANGEDCO

Time

Final Load

Reference

RFGMO

Correction Actual Load

Actual

Frequency

06:49:43 357.87 0 343.58 49.97

06:49:44 357.87 0 343.83 49.97

06:49:45 357.87 0 343.39 49.97

06:49:46 357.87 0 343.00 49.97

06:49:47 357.87 0 343.03 49.97

06:49:48 357.87 0 343.55 49.97

06:49:49 357.87 0 348.22 49.96

06:49:50 357.87 0 347.78 49.91

06:49:51 357.87 0 344.43 49.87

06:49:52 367.69 9.826 344.02 49.86

06:49:53 373.06 15.1964 345.56 49.86

06:49:54 376.98 19.1101 346.02 49.83

06:49:55 380.36 22.4964 344.27 49.81

06:49:56 382.84 25 343.61 49.80

06:49:57 382.87 25 343.94 49.80

06:49:58 382.87 25 344.60 49.79

06:49:59 382.87 25 344.18 49.79

06:50:00 382.87 25 343.63 49.78

06:50:01 382.87 25 343.88 49.77

06:50:02 382.87 25 344.10 49.77

06:50:03 382.89 25 344.07 49.77

06:50:04 382.87 25 343.17 49.77

06:50:05 382.89 25 343.33 49.77

06:50:06 382.86 25 343.83 49.77

06:50:07 382.88 25 343.50 49.77

06:50:08 382.88 25 343.39 49.77

06:50:09 382.88 25 343.19 49.77

06:50:10 382.88 25 343.52 49.77

06:50:11 382.88 25 343.03 49.77

06:50:12 382.88 25 343.88 49.78

06:50:13 382.91 25 343.69 49.78

06:50:14 382.88 25 344.16 49.78

06:50:15 382.88 25 343.80 49.78

06:50:16 382.88 25 344.27 49.78

06:50:17 382.88 25 343.44 49.78

06:50:18 382.85 25 343.33 49.78

06:50:19 382.85 25 343.55 49.78

06:50:20 382.85 25 343.08 49.78

06:50:21 382.85 25 343.52 49.78

06:50:22 382.85 25 343.96 49.78

06:50:23 382.83 25 343.91 49.78

06:50:24 382.83 25 343.11 49.78

06:50:25 382.81 25 343.77 49.78

06:50:26 382.77 25 343.66 49.78

06:50:27 382.77 25 343.55 49.78

06:50:28 382.77 25 343.22 49.78

06:50:29 382.77 25 343.72 49.78

06:50:30 382.77 25 344.02 49.77

Courtesy: RGMO web group, SR


RGMO block operated

But no change in actual MW ???

750 MW


Units 5 & 6 of ABCDEF station

NCTPS, TANGEDCO

Time Frequency

UNIT-5 UNIT-6

LOAD

FGMO

Correction LOAD

FGMO

Correction

06:50:00 49.97 214.34 0.00 214.45 0.00

06:50:01 49.96 213.71 0.00 213.99 0.00

06:50:02 49.96 213.96 0.00 213.95 0.00

06:50:03 49.96 213.99 0.00 214.37 0.00

06:50:04 49.95 214.02 0.00 214.37 0.00

06:50:05 49.93 215.89 0.00 216.61 0.00

06:50:06 49.86 215.48 0.00 215.52 0.00

06:50:07 49.85 213.84 0.00 214.17 0.19

06:50:08 49.83 213.80 0.00 213.99 2.11

06:50:09 49.81 214.00 1.37 214.42 3.02

06:50:10 49.81 214.26 2.13 214.00 3.02

06:50:11 49.79 214.45 3.11 214.00 4.02

06:50:12 49.79 214.00 4.20 213.88 5.23

06:50:13 49.77 213.51 5.29 214.10 6.34

06:50:14 49.76 213.79 6.14 214.46 7.97

06:50:15 49.78 214.02 7.14 214.51 8.54

06:50:16 49.78 213.83 7.89 214.58 8.54

06:50:17 49.76 214.07 8.47 214.58 8.97

06:50:18 49.75 214.22 8.97 214.93 9.31

06:50:19 49.76 214.70 9.28 215.00 9.58

06:50:20 49.76 214.96 9.55 214.65 9.78

06:50:21 49.76 215.01 9.76 215.27 10.07

06:50:22 49.77 215.17 9.92 215.40 10.16

06:50:23 49.77 215.52 10.05 215.06 10.24

06:50:24 49.77 215.83 10.15 215.30 10.29

06:50:25 49.77 215.76 10.23 215.30 10.34

06:50:26 49.77 215.90 10.29 215.61 10.40

06:50:27 49.78 216.12 10.33 215.38 10.40

06:50:28 49.78 216.49 10.37 215.98 10.40

06:50:29 49.78 216.27 10.40 215.89 10.44

06:50:30 49.78 216.00 10.35 215.64 10.44


Operating Limits & TG response

– Generating Units

RGMO block

operated

But no change

in actual MW ???

750 MW

Time

RFGMO

Correction Actual Load Actual Frequency

49:48.0 0 215.3105 49.9724

49:48.2 0 215.3105 49.9724

49:48.4 0 215.3105 49.9724

49:48.6 0 215.3105 49.9724

49:48.8 0 216.2341 49.9621

49:49.0 0 216.2341 49.9621

49:49.2 0 216.2341 49.9621

49:49.4 0 216.2341 49.9621

49:49.6 0 216.2341 49.9621

49:49.8 0 216.6395 49.9077

49:50.0 0 216.6395 49.9077

49:50.2 0 216.6395 49.9077

49:50.4 0 216.6395 49.9077

49:50.6 0 215.4571 49.8578

49:50.8 0 215.4571 49.8578

49:51.0 0 215.4571 49.8578

49:51.2 0 215.4571 49.8578

49:51.4 0 215.4571 49.8578

49:51.6 0 215.4571 49.8578

49:51.8 5.4414 214.1394 49.8509

49:52.0 5.4414 214.1394 49.8509

49:52.2 5.4414 214.1394 49.8509

49:52.4 5.4414 214.1394 49.8509

49:52.6 7.8997 214.9839 49.8489

49:52.8 7.8997 214.9839 49.8489

49:53.0 7.8997 214.9839 49.8489

49:53.2 7.8997 214.9839 49.8489

49:53.4 7.8997 214.9839 49.8489

49:53.6 7.8997 214.9839 49.8489

49:53.8 8.7842 215.4006 49.823

49:54.0 8.7842 215.4006 49.823

49:54.2 8.7842 215.4006 49.823

49:54.4 8.7842 215.4006 49.823

49:54.6 10.5 214.6574 49.7985

49:54.8 10.5 214.6574 49.7985

49:55.0 10.5 214.6574 49.7985

49:55.2 10.5 214.6574 49.7985

49:55.4 10.5 214.6574 49.7985

49:55.6 10.5 214.4096 49.7916

49:55.8 10.5 214.4096 49.7916

49:56.0 10.5 214.4096 49.7916

49:56.2 10.5 214.4096 49.7916

49:56.4 10.5 214.4096 49.7916

49:56.6 10.5 214.4096 49.7916

Time RFGMO Correction Actual Load Actual Frequency

49:43.6 4.6109 215.5611 49.9748

49:43.8 4.6109 215.5611 49.9748

49:44.0 4.6109 215.5611 49.9748

49:44.2 4.6696 215.4924 49.9748

49:44.4 4.6696 215.4924 49.9748

49:44.6 4.6696 215.4924 49.9748

49:44.8 4.6696 215.4924 49.9748

49:45.0 4.6696 215.4924 49.9748

49:45.2 4.8867 215.149 49.9748

49:45.4 4.8867 215.149 49.9748

49:45.6 4.8867 215.149 49.9748

49:45.8 4.8867 215.149 49.9748

49:46.0 4.8867 215.149 49.9748

49:46.2 5.0501 215.0117 49.9748

49:46.4 5.0501 215.0117 49.9748

49:46.6 5.0501 215.0117 49.9748

49:46.8 5.0501 215.0117 49.9748

49:47.0 5.0501 215.0117 49.9748

49:47.2 5.0501 215.0117 49.9748

49:47.4 4.8361 215.7671 49.9748

49:47.6 4.8361 215.7671 49.9748

49:47.8 4.8361 215.7671 49.9748

49:48.0 4.8361 215.7671 49.9748

49:48.2 4.9212 216.6827 49.9748

49:48.4 4.9212 216.6827 49.9748

49:48.6 4.9212 216.6827 49.9748

49:48.8 4.9212 216.6827 49.9748

49:49.0 4.9212 216.6827 49.9748

49:49.2 5.0593 217.1291 49.9748

49:49.4 5.0593 217.1291 49.9748

49:49.6 5.0593 217.1291 49.9748

49:49.8 5.0593 217.1291 49.9748

49:50.0 5.0593 217.1291 49.9748

49:50.2 6.7485 215.8931 49.9352

49:50.4 6.7485 215.8931 49.9352

49:50.6 6.7485 215.8931 49.9352

49:50.8 6.7485 215.8931 49.9352

49:51.0 6.7485 215.8931 49.9352

49:51.2 6.7485 215.8931 49.9352

49:51.4 10.5 214.9087 49.8878

49:51.6 10.5 214.9087 49.8878

49:51.8 10.5 214.9087 49.8878

49:52.0 10.5 214.9087 49.8878

49:52.2 10.5 215.4924 49.8878

49:52.4 10.5 215.4924 49.8878

49:52.6 10.5 215.4924 49.8878

49:52.8 10.5 215.4924 49.8878

49:53.0 10.5 215.4924 49.8878


Unit 3 of ABCDEF station Unit 4 of ABCDEF station

NCTPS, TANGEDCO Courtesy: RGMO web group, SR


RGMO block

operated

But no change

in actual MW

Five Units

55 MW

Response NIL

Halt time of 3 Mins

750 MW

NCTPS, TANGEDCO

Turbine Control System


Pressure correction

Load limiter

Frequency Influence

Frequency switch

On/Off Case study 2

Case study 1

750 MW

IEGC 5.2 (g)


NCTPS, TANGEDCO

Frequency switch On/Off

Visibility of RGMO status of Generating units in State LDC

room via SCADA

750 MW

NCTPS, TANGEDCO

SRPC’s appreciation for putting up –

visibility of RGMO status at State LDC

750 MW










RGMO

Performance

OK

Not OK



TG response

100% Responsibility

with GU only

NCTPS, TANGEDCO

750 MW

Unit

#/Station

MCR of

Machines

on Bar

5% of

MCR

Current

generation

RGMO

Expected 5%

of current

generation

Actual

RGMO

response

1/wxyz 500 25 405 20.25 xx

2/wxyz 500 25 432 21.6 yy

3/wxyz 500 25 468 23.4 zz

1/abcde 210 10.5 201 10.05 aa

2/abcde 210 10.5 185 9.25 bb

Total 96 84.55 NCTPS, TANGEDCO

Analysis - Generating Units & SRLDC 750 MW

23rd June 2014


Now it is not 1000 MW. Thanks to Shri.Shrivastavaji

Analysis - Generating Units & SRLDC 750 MW

NCTPS, TANGEDCO

1003 985 999 1014

886

1028 997

1125 1104 1099

-9

160

29

-178

276

61 69-25

359

3

-400

-200

0

200

400

600

800

1000

1200

1 2 3 4 5 6 7 8 9 10

MW

Incidents

RGMO Expected Vs Response Frequency dip




Target around 1000 MW


Sep 2013

750 MW


Ferquency dip

Apr to Sep 2015

883.4

638.7714.3 750.5 725.7

159.2

23.5118.5 157.3 148.2

0.0

200.0

400.0

600.0

800.0

1000.0

1 2 3 4 5

Incident

MW


NCTPS, TANGEDCO

Courtesy: SRLDC

750 MW










RGMO

Performance

OK

Not OK



TG response

100% Responsibility

with GU only

NCTPS, TANGEDCO

From

750 MW

Date of incident : 02 Mar 2015 Unit 7 of ABCDEF station

NCTPS, TANGEDCO

Time

Final Load

Reference

RFGMO

Correction Actual Load

Actual

Frequency

06:49:43 357.87 0 343.58 49.97

06:49:44 357.87 0 343.83 49.97

06:49:45 357.87 0 343.39 49.97

06:49:46 357.87 0 343.00 49.97

06:49:47 357.87 0 343.03 49.97

06:49:48 357.87 0 343.55 49.97

06:49:49 357.87 0 348.22 49.96

06:49:50 357.87 0 347.78 49.91

06:49:51 357.87 0 344.43 49.87

06:49:52 367.69 9.826 344.02 49.86

06:49:53 373.06 15.1964 345.56 49.86

06:49:54 376.98 19.1101 346.02 49.83

06:49:55 380.36 22.4964 344.27 49.81

06:49:56 382.84 25 343.61 49.80

06:49:57 382.87 25 343.94 49.80

06:49:58 382.87 25 344.60 49.79

06:49:59 382.87 25 344.18 49.79

06:50:00 382.87 25 343.63 49.78

06:50:01 382.87 25 343.88 49.77

06:50:02 382.87 25 344.10 49.77

06:50:03 382.89 25 344.07 49.77

06:50:04 382.87 25 343.17 49.77

06:50:05 382.89 25 343.33 49.77

06:50:06 382.86 25 343.83 49.77

06:50:07 382.88 25 343.50 49.77

06:50:08 382.88 25 343.39 49.77

06:50:09 382.88 25 343.19 49.77

06:50:10 382.88 25 343.52 49.77

06:50:11 382.88 25 343.03 49.77

06:50:12 382.88 25 343.88 49.78

06:50:13 382.91 25 343.69 49.78

06:50:14 382.88 25 344.16 49.78

06:50:15 382.88 25 343.80 49.78

06:50:16 382.88 25 344.27 49.78

06:50:17 382.88 25 343.44 49.78

06:50:18 382.85 25 343.33 49.78

06:50:19 382.85 25 343.55 49.78

06:50:20 382.85 25 343.08 49.78

06:50:21 382.85 25 343.52 49.78

06:50:22 382.85 25 343.96 49.78

06:50:23 382.83 25 343.91 49.78

06:50:24 382.83 25 343.11 49.78

06:50:25 382.81 25 343.77 49.78

06:50:26 382.77 25 343.66 49.78

06:50:27 382.77 25 343.55 49.78

06:50:28 382.77 25 343.22 49.78

06:50:29 382.77 25 343.72 49.78

06:50:30 382.77 25 344.02 49.77


Implementation – Generating Units, OEMs +344*0,05 = 17.2 MW

This shall be 17 MW It is not 25 MW

750 MW

NCTPS, TANGEDCO

DATE & TIME EHG POSITION Actual MW TURBINE SPEED MS press. F infl.

24-09-2015 01:03 80.96 192.8 2997.1 123.4 0.5

24-09-2015 01:03 80.91 192.7 3000.6 123.3 0.5

24-09-2015 01:03 81.15 192.8 2997.1 123.4 0.5

24-09-2015 01:03 81.1 193 2997.1 123.4 0.4

24-09-2015 01:03 80.96 192.8 2997.1 123.5 0.4

24-09-2015 01:03 81.01 193 2997.1 123.4 1.6

24-09-2015 01:03 81.25 193 2997.1 123.4 4.4

24-09-2015 01:03 81.79 192.8 2997.1 123.4 4.4

24-09-2015 01:03 82.32 193 2997.1 123.3 4.3

24-09-2015 01:03 82.76 192.8 2997.1 123.4 4.4

24-09-2015 01:03 82.96 192.8 2997.1 123.3 4.4

24-09-2015 01:03 83.54 192.8 2997.1 123.4 4.4

24-09-2015 01:03 83.74 193 2997.1 123.3 4.4

24-09-2015 01:03 84.38 193 2997.1 123.3 4.3

24-09-2015 01:03 85.06 192.8 2997.1 123.3 6.6

24-09-2015 01:03 85.79 192.8 2997.1 123.3 6.7

24-09-2015 01:03 86.08 192.8 2997.1 123.3 6.8

24-09-2015 01:03 87.01 192.7 2997.1 123.2 6.8

24-09-2015 01:03 87.79 193 2997.1 123.3 6.8

24-09-2015 01:03 88.28 193 2997.1 123.3 9.9

24-09-2015 01:03 89.21 193 2997.1 123.3 9.9

24-09-2015 01:03 90.38 193 2997.1 123.3 10

24-09-2015 01:03 91.55 193 2997.1 123.3 9.9

24-09-2015 01:03 92.53 193 2997.1 123.3 9.9

24-09-2015 01:03 93.46 192.8 2997.1 123.3 9.8

24-09-2015 01:03 94.53 193 2997.1 123.3 9.9

24-09-2015 01:03 95.7 193 2997.1 123.3 9.8

24-09-2015 01:03 96.39 193 2997.1 123.3 9.9

24-09-2015 01:03 97.36 193 2997.1 123.3 9.9

24-09-2015 01:03 97.9 193 2997.1 123.4 9.9

24-09-2015 01:03 97.95 193 2997.1 123.3 9.9

24-09-2015 01:03 98.05 193 2997.1 123.3 10

24-09-2015 01:03 98.05 192.8 2997.1 123.3 9.9

24-09-2015 01:03 98.05 192.8 2997.1 123.3 10

24-09-2015 01:03 98.14 192.8 2997.1 123.3 9.8

24-09-2015 01:03 98.05 192.8 2997.1 123.3 9.9

24-09-2015 01:03 98.05 192.8 2997.1 123.3 9.8

24-09-2015 01:03 98.05 192.8 2997.1 123.3 9.9

24-09-2015 01:03 98.05 192.7 2997.1 123.3 9.9

24-09-2015 01:03 98.05 192.8 2997.1 123.3 9.9

24-09-2015 01:03 98.05 192.8 2997.1 123.3 9.9

24-09-2015 01:03 98.05 192.8 2997.1 123.3 10

24-09-2015 01:03 98.1 192.8 2997.1 123.3 9.9

24-09-2015 01:03 98.14 192.8 2997.1 123.3 9.9

24-09-2015 01:03 98.1 193 2997.1 123.3 9.9

24-09-2015 01:03 98.05 193 2997.1 123.2 9.9

24-09-2015 01:03 98.1 192.8 2997.1 123.3 9.9

24-09-2015 01:03 98.05 193.1 2997.1 123.3 9.9

24-09-2015 01:03 98.14 193 2997.1 123.3 9.8

24-09-2015 01:03 98.05 193 2997.1 123.3 9.9

24-09-2015 01:03 98.14 193 2997.1 123.3 9.9

24-09-2015 01:03 98.05 193 2997.1 123.3 9.9

24-09-2015 01:03 98.05 193 2997.1 123.3 9.9

24-09-2015 01:03 98.05 192.8 2997.1 123.3 9.9

24-09-2015 01:03 98.05 192.8 2997.1 123.3 9.9

24-09-2015 01:03 98.05 192.8 2997.1 123.3 9.9

24-09-2015 01:03 98.05 193 2997.1 123.3 9.9

24-09-2015 01:03 98.05 193 2997.1 123.3 9.9

24-09-2015 01:04 98.05 193 2997.1 123.3 9.8

24-09-2015 01:04 98.05 193 2997.1 123.3 9.9

24-09-2015 01:04 98.05 193 2997.1 123.3 9.9

24-09-2015 01:04 98.05 193 2997.1 123.3 9.9

24-09-2015 01:04 98.14 193 2997.1 123.3 9.8

24-09-2015 01:04 98.05 192.8 2997.1 123.3 9.9

24-09-2015 01:04 98.05 193 2997.1 123.3 9.9

24-09-2015 01:04 98.1 193 2997.1 123.3 9.9

24-09-2015 01:04 98.05 193 2997.1 123.3 10

24-09-2015 01:04 98.05 192.8 2997.1 123.3 10

24-09-2015 01:04 98.05 193.1 2997.1 123.4 9.9

24-09-2015 01:04 98.05 193 2997.1 123.4 9.9

24-09-2015 01:04 98.05 193 2997.1 123.3 9.9

24-09-2015 01:04 98.14 193 2997.1 123.3 9.9

24-09-2015 01:04 98.05 193.1 2997.1 123.3 9.8

24-09-2015 01:04 98.05 193 2997.1 123.3 9.9

24-09-2015 01:04 98.05 193 2997.1 123.3 9.8

24-09-2015 01:04 98.05 193 2997.1 123.3 9.9

24-09-2015 01:04 98.14 193.1 2997.1 123.3 9.8

+193*0,05 = 9.65 MW

aRTPP data from EXCEL file.

NCTPS, TANGEDCO

OEM has to introduce this logic in the

software implementation block so as to

decide the correct RGMO value

as required in IEGC

750 MW

IEGC 5.2 (f)

NCTPS, TANGEDCO


750 MW

Load

Frequency Influence

Speed

4 Hrs trend Tuticorin TPS TANGEDCO

750 MW 20.11.2014

NCTPS, TANGEDCO

Load Frequency Influence

Speed

4 Hrs trend 24.09.2015 Tuticorin TPS TANGEDCO

750 MW





RGMO

Performance

OK

Not OK



100% Responsibility

with GU only

Ripple factor of 0.03 Hz plays a vital role

in capturing the RGMO requirement and

The machine to be responded.

NCTPS, TANGEDCO

750 MW

Date

Time

Frequency

From To From To

8/8/2014 11:31 11:32 49.85 49.74

9/8/2014 6:00 6:01 50.08 50.19

10/8/2014 14:31 14:32 50.06 49.93

Instances posted by SRLDC for August 2014

NCTPS, TANGEDCO


Incidents identification – RGMO Software block, GU & SRLDC 750 MW


NCTPS, TANGEDCO

750 MW


SRLDC started changing the methodology

in identifying the RGMO incidents NCTPS, TANGEDCO

Incidents identification – RGMO Software block, GU & SRLDC 750 MW

Implementation – Generating Units




RGMO

Performance

OK

Not OK



100% Responsibility

with GU only

With RF

Without RF

NCTPS, TANGEDCO

750 MW

Time

RFGMO

Correction Actual Load Actual Frequency

49:48.0 0 215.3105 49.9724

49:48.2 0 215.3105 49.9724

49:48.4 0 215.3105 49.9724

49:48.6 0 215.3105 49.9724

49:48.8 0 216.2341 49.9621

49:49.0 0 216.2341 49.9621

49:49.2 0 216.2341 49.9621

49:49.4 0 216.2341 49.9621

49:49.6 0 216.2341 49.9621

49:49.8 0 216.6395 49.9077

49:50.0 0 216.6395 49.9077

49:50.2 0 216.6395 49.9077

49:50.4 0 216.6395 49.9077

49:50.6 0 215.4571 49.8578

49:50.8 0 215.4571 49.8578

49:51.0 0 215.4571 49.8578

49:51.2 0 215.4571 49.8578

49:51.4 0 215.4571 49.8578

49:51.6 0 215.4571 49.8578

49:51.8 5.4414 214.1394 49.8509

49:52.0 5.4414 214.1394 49.8509

49:52.2 5.4414 214.1394 49.8509

49:52.4 5.4414 214.1394 49.8509

49:52.6 7.8997 214.9839 49.8489

49:52.8 7.8997 214.9839 49.8489

49:53.0 7.8997 214.9839 49.8489

49:53.2 7.8997 214.9839 49.8489

49:53.4 7.8997 214.9839 49.8489

49:53.6 7.8997 214.9839 49.8489

49:53.8 8.7842 215.4006 49.823

49:54.0 8.7842 215.4006 49.823

49:54.2 8.7842 215.4006 49.823

49:54.4 8.7842 215.4006 49.823

49:54.6 10.5 214.6574 49.7985

49:54.8 10.5 214.6574 49.7985

49:55.0 10.5 214.6574 49.7985

49:55.2 10.5 214.6574 49.7985

49:55.4 10.5 214.6574 49.7985

49:55.6 10.5 214.4096 49.7916

49:55.8 10.5 214.4096 49.7916

49:56.0 10.5 214.4096 49.7916

49:56.2 10.5 214.4096 49.7916

49:56.4 10.5 214.4096 49.7916

49:56.6 10.5 214.4096 49.7916

Time RFGMO Correction Actual Load Actual Frequency

49:43.6 4.6109 215.5611 49.9748

49:43.8 4.6109 215.5611 49.9748

49:44.0 4.6109 215.5611 49.9748

49:44.2 4.6696 215.4924 49.9748

49:44.4 4.6696 215.4924 49.9748

49:44.6 4.6696 215.4924 49.9748

49:44.8 4.6696 215.4924 49.9748

49:45.0 4.6696 215.4924 49.9748

49:45.2 4.8867 215.149 49.9748

49:45.4 4.8867 215.149 49.9748

49:45.6 4.8867 215.149 49.9748

49:45.8 4.8867 215.149 49.9748

49:46.0 4.8867 215.149 49.9748

49:46.2 5.0501 215.0117 49.9748

49:46.4 5.0501 215.0117 49.9748

49:46.6 5.0501 215.0117 49.9748

49:46.8 5.0501 215.0117 49.9748

49:47.0 5.0501 215.0117 49.9748

49:47.2 5.0501 215.0117 49.9748

49:47.4 4.8361 215.7671 49.9748

49:47.6 4.8361 215.7671 49.9748

49:47.8 4.8361 215.7671 49.9748

49:48.0 4.8361 215.7671 49.9748

49:48.2 4.9212 216.6827 49.9748

49:48.4 4.9212 216.6827 49.9748

49:48.6 4.9212 216.6827 49.9748

49:48.8 4.9212 216.6827 49.9748

49:49.0 4.9212 216.6827 49.9748

49:49.2 5.0593 217.1291 49.9748

49:49.4 5.0593 217.1291 49.9748

49:49.6 5.0593 217.1291 49.9748

49:49.8 5.0593 217.1291 49.9748

49:50.0 5.0593 217.1291 49.9748

49:50.2 6.7485 215.8931 49.9352

49:50.4 6.7485 215.8931 49.9352

49:50.6 6.7485 215.8931 49.9352

49:50.8 6.7485 215.8931 49.9352

49:51.0 6.7485 215.8931 49.9352

49:51.2 6.7485 215.8931 49.9352

49:51.4 10.5 214.9087 49.8878

49:51.6 10.5 214.9087 49.8878

49:51.8 10.5 214.9087 49.8878

49:52.0 10.5 214.9087 49.8878

49:52.2 10.5 215.4924 49.8878

49:52.4 10.5 215.4924 49.8878

49:52.6 10.5 215.4924 49.8878

49:52.8 10.5 215.4924 49.8878

49:53.0 10.5 215.4924 49.8878


Unit 3 of ABCDEF station Unit 4 of ABCDEF station

NCTPS, TANGEDCO Courtesy: RGMO web group, SR


Frequency

value

Shown

once in

200 milli seconds

In this case

the ripple

factor is

Captured

correctly

Micro processor

running at 50 milli second

For five cycles, then

250 milli seond

PMU data used at SRLDC

750 MW

NCTPS, TANGEDCO

DATE & TIME EHG POSITION Actual MW TURBINE

SPEED MS press. F infl.

24-09-2015 00:37 62.79 196.2 3000.6 130 0.4

24-09-2015 00:37 62.79 196.4 3000.6 129.9 0.5

24-09-2015 00:37 62.79 196.7 3000.6 129.9 0.5

24-09-2015 00:37 62.79 196.5 3000.6 129.9 0.5

24-09-2015 00:37 62.74 196.4 3000.6 129.9 0.5

24-09-2015 00:38 63.04 196.4 3000.6 130 0.5

24-09-2015 00:38 62.7 196.4 3000.6 130 0.5

24-09-2015 00:38 62.84 196.2 3000.6 129.9 0.4

24-09-2015 00:38 62.84 196.1 3000.6 130 0.5

24-09-2015 00:38 62.6 196.1 3000.6 130 1.3

24-09-2015 00:38 63.13 196.2 3000.6 130 2.7

24-09-2015 00:38 63.33 195.9 3000.6 129.9 2.7

24-09-2015 00:38 63.77 195.9 3000.6 129.8 2.7

24-09-2015 00:38 63.67 196.4 2998.8 129.9 2.8

24-09-2015 00:38 64.21 196.5 3000.6 129.9 2.8

24-09-2015 00:38 64.21 196.5 3000.6 129.8 2.9

24-09-2015 00:38 64.55 196.5 3000.6 129.8 5.5

24-09-2015 00:38 65.14 196.5 2998.8 129.8 6.6

24-09-2015 00:38 65.72 196.5 3000.6 129.8 6.7

24-09-2015 00:38 66.16 196.8 2998.8 129.8 6.5

24-09-2015 00:38 66.8 196.8 2998.8 129.7 6.5

24-09-2015 00:38 67.48 197 3000.6 129.7 6.6

24-09-2015 00:38 67.68 197.2 3000.6 129.6 6.6

24-09-2015 00:38 68.12 197.5 3000.6 129.6 6.6

24-09-2015 00:38 68.31 197.8 3000.6 129.5 6.6

24-09-2015 00:38 69.09 197.8 2998.8 129.5 6.5

24-09-2015 00:38 69.43 198.1 2998.8 129.4 6.6

24-09-2015 00:38 69.73 198.1 3000.6 129.4 6.5

24-09-2015 00:38 70.46 198.4 2998.8 129.4 9.8

24-09-2015 00:38 70.9 198.4 2998.8 129.4 9.9

24-09-2015 00:38 71.58 198.4 3000.6 129.4 9.9

24-09-2015 00:38 72.22 198.7 3000.6 129.3 9.8

24-09-2015 00:38 72.95 198.7 3000.6 129.4 9.9

24-09-2015 00:38 73.39 199 3000.6 129.2 9.9

24-09-2015 00:38 73.97 199 3000.6 129.2 9.9

24-09-2015 00:38 74.76 199.2 2998.8 129.2 9.9

24-09-2015 00:38 75.1 199.2 3000.6 129.2 9.9

24-09-2015 00:38 75.73 199.3 2998.8 129.2 9.9

24-09-2015 00:38 76.32 199.3 2998.8 129.2 9.9

24-09-2015 00:38 76.61 199.3 3000.6 129.2 9.9

24-09-2015 00:38 77.05 199.6 3000.6 129.2 10

24-09-2015 00:38 78.13 199.8 2998.8 129.2 9.9

24-09-2015 00:38 78.22 199.8 3000.6 129.1 10

24-09-2015 00:38 78.81 199.9 3000.6 129 10

24-09-2015 00:38 79.15 200.1 2998.8 129 9.9

24-09-2015 00:38 79.59 200.1 3000.6 129 9.9

24-09-2015 00:38 80.08 200.1 3000.6 129 9.9

24-09-2015 00:38 80.42 200.3 2998.8 128.9 9.9

24-09-2015 00:38 81.01 200.4 3000.6 128.9 10

24-09-2015 00:38 81.49 200.4 3000.6 129 9.9

24-09-2015 00:38 81.54 200.6 3000.6 128.9 9.9

24-09-2015 00:38 82.23 200.7 2998.8 128.8 9.9

24-09-2015 00:38 82.42 200.6 3000.6 128.8 10

24-09-2015 00:38 82.62 200.6 2998.8 128.8 9.8

24-09-2015 00:38 83.4 200.7 3000.6 128.8 9.9

24-09-2015 00:38 83.59 200.4 3000.6 128.8 9.9

24-09-2015 00:38 83.89 200.6 2998.8 128.8 9.9

24-09-2015 00:38 84.28 200.6 2998.8 128.8 9.8

24-09-2015 00:38 84.67 200.6 3000.6 128.7 9.9

24-09-2015 00:38 85.06 200.7 2998.8 128.7 9.8

24-09-2015 00:38 85.55 200.9 2998.8 128.7 10

24-09-2015 00:38 85.74 200.7 3000.6 128.8 9.8

24-09-2015 00:38 85.94 200.7 3000.6 128.8 9.9

24-09-2015 00:38 86.23 200.9 2998.8 128.8 9.9

24-09-2015 00:38 86.72 200.7 3000.6 128.7 9.9

24-09-2015 00:39 87.21 200.9 2998.8 128.8 9.8

24-09-2015 00:39 87.26 201 2998.8 128.7 9.9

24-09-2015 00:39 87.79 201.2 3000.6 128.7 9.9

24-09-2015 00:39 87.99 201.2 3000.6 128.7 9.9

24-09-2015 00:39 88.38 201 2998.8 128.6 9.9

24-09-2015 00:39 88.67 201 3000.6 128.7 9.9

24-09-2015 00:39 88.96 201 3000.6 128.7 9.9

24-09-2015 00:39 89.4 201 2998.8 128.6 9.9

24-09-2015 00:39 89.55 201.2 2998.8 128.6 9.8

24-09-2015 00:39 89.99 201.2 3000.6 128.6 9.9

24-09-2015 00:39 90.04 201.3 2998.8 128.6 9.9

24-09-2015 00:39 90.63 201 3000.6 128.6 10

24-09-2015 00:39 90.67 201.2 3000.6 128.6 9.9

24-09-2015 00:39 91.06 201 2998.8 128.5 10

24-09-2015 00:39 91.41 201 2998.8 128.6 9.8

24-09-2015 00:39 91.46 201.2 3000.6 128.6 9.9

XYZAB Station Unit 4

750 MW No 0.03 Hz at all

NCTPS, TANGEDCO

DATE & TIME EHG POSITION Actual MW TURBINE

SPEED MS press. F infl.

24-09-2015 00:37 62.79 196.2 3000.6 130 0.4

24-09-2015 00:37 62.79 196.4 3000.6 129.9 0.5

24-09-2015 00:37 62.79 196.7 3000.6 129.9 0.5

24-09-2015 00:37 62.79 196.5 3000.6 129.9 0.5

24-09-2015 00:37 62.74 196.4 3000.6 129.9 0.5

24-09-2015 00:38 63.04 196.4 3000.6 130 0.5

24-09-2015 00:38 62.7 196.4 3000.6 130 0.5

24-09-2015 00:38 62.84 196.2 3000.6 129.9 0.4

24-09-2015 00:38 62.84 196.1 3000.6 130 0.5

24-09-2015 00:38 62.6 196.1 3000.6 130 1.3

24-09-2015 00:38 63.13 196.2 3000.6 130 2.7

24-09-2015 00:38 63.33 195.9 3000.6 129.9 2.7

24-09-2015 00:38 63.77 195.9 3000.6 129.8 2.7

24-09-2015 00:38 63.67 196.4 2998.8 129.9 2.8

24-09-2015 00:38 64.21 196.5 3000.6 129.9 2.8

24-09-2015 00:38 64.21 196.5 3000.6 129.8 2.9

24-09-2015 00:38 64.55 196.5 3000.6 129.8 5.5

24-09-2015 00:38 65.14 196.5 2998.8 129.8 6.6

24-09-2015 00:38 65.72 196.5 3000.6 129.8 6.7

24-09-2015 00:38 66.16 196.8 2998.8 129.8 6.5

24-09-2015 00:38 66.8 196.8 2998.8 129.7 6.5

24-09-2015 00:38 67.48 197 3000.6 129.7 6.6

24-09-2015 00:38 67.68 197.2 3000.6 129.6 6.6

24-09-2015 00:38 68.12 197.5 3000.6 129.6 6.6

24-09-2015 00:38 68.31 197.8 3000.6 129.5 6.6

24-09-2015 00:38 69.09 197.8 2998.8 129.5 6.5

24-09-2015 00:38 69.43 198.1 2998.8 129.4 6.6

24-09-2015 00:38 69.73 198.1 3000.6 129.4 6.5

24-09-2015 00:38 70.46 198.4 2998.8 129.4 9.8

24-09-2015 00:38 70.9 198.4 2998.8 129.4 9.9

24-09-2015 00:38 71.58 198.4 3000.6 129.4 9.9

24-09-2015 00:38 72.22 198.7 3000.6 129.3 9.8

24-09-2015 00:38 72.95 198.7 3000.6 129.4 9.9

24-09-2015 00:38 73.39 199 3000.6 129.2 9.9

24-09-2015 00:38 73.97 199 3000.6 129.2 9.9

24-09-2015 00:38 74.76 199.2 2998.8 129.2 9.9

24-09-2015 00:38 75.1 199.2 3000.6 129.2 9.9

24-09-2015 00:38 75.73 199.3 2998.8 129.2 9.9

24-09-2015 00:38 76.32 199.3 2998.8 129.2 9.9

24-09-2015 00:38 76.61 199.3 3000.6 129.2 9.9

24-09-2015 00:38 77.05 199.6 3000.6 129.2 10

24-09-2015 00:38 78.13 199.8 2998.8 129.2 9.9

24-09-2015 00:38 78.22 199.8 3000.6 129.1 10

24-09-2015 00:38 78.81 199.9 3000.6 129 10

24-09-2015 00:38 79.15 200.1 2998.8 129 9.9

24-09-2015 00:38 79.59 200.1 3000.6 129 9.9

24-09-2015 00:38 80.08 200.1 3000.6 129 9.9

24-09-2015 00:38 80.42 200.3 2998.8 128.9 9.9

24-09-2015 00:38 81.01 200.4 3000.6 128.9 10

24-09-2015 00:38 81.49 200.4 3000.6 129 9.9

24-09-2015 00:38 81.54 200.6 3000.6 128.9 9.9

24-09-2015 00:38 82.23 200.7 2998.8 128.8 9.9

24-09-2015 00:38 82.42 200.6 3000.6 128.8 10

24-09-2015 00:38 82.62 200.6 2998.8 128.8 9.8

24-09-2015 00:38 83.4 200.7 3000.6 128.8 9.9

24-09-2015 00:38 83.59 200.4 3000.6 128.8 9.9

24-09-2015 00:38 83.89 200.6 2998.8 128.8 9.9

24-09-2015 00:38 84.28 200.6 2998.8 128.8 9.8

24-09-2015 00:38 84.67 200.6 3000.6 128.7 9.9

24-09-2015 00:38 85.06 200.7 2998.8 128.7 9.8

24-09-2015 00:38 85.55 200.9 2998.8 128.7 10

24-09-2015 00:38 85.74 200.7 3000.6 128.8 9.8

24-09-2015 00:38 85.94 200.7 3000.6 128.8 9.9

24-09-2015 00:38 86.23 200.9 2998.8 128.8 9.9

24-09-2015 00:38 86.72 200.7 3000.6 128.7 9.9

24-09-2015 00:39 87.21 200.9 2998.8 128.8 9.8

24-09-2015 00:39 87.26 201 2998.8 128.7 9.9

24-09-2015 00:39 87.79 201.2 3000.6 128.7 9.9

24-09-2015 00:39 87.99 201.2 3000.6 128.7 9.9

24-09-2015 00:39 88.38 201 2998.8 128.6 9.9

24-09-2015 00:39 88.67 201 3000.6 128.7 9.9

24-09-2015 00:39 88.96 201 3000.6 128.7 9.9

24-09-2015 00:39 89.4 201 2998.8 128.6 9.9

24-09-2015 00:39 89.55 201.2 2998.8 128.6 9.8

24-09-2015 00:39 89.99 201.2 3000.6 128.6 9.9

24-09-2015 00:39 90.04 201.3 2998.8 128.6 9.9

24-09-2015 00:39 90.63 201 3000.6 128.6 10

24-09-2015 00:39 90.67 201.2 3000.6 128.6 9.9

24-09-2015 00:39 91.06 201 2998.8 128.5 10

24-09-2015 00:39 91.41 201 2998.8 128.6 9.8

24-09-2015 00:39 91.46 201.2 3000.6 128.6 9.9

24Sep 2015 - No RGMO incident occurred

0.03 Hz * 60 = 1.8 RPM.

Valve % opening

Fall in pressure will close the valve

NCTPS, TANGEDCO

Load Frequency Influence

Speed

4 Hrs trend 24.09.2015 Tuticorin TPS TANGEDCO

750 MW

NCTPS, TANGEDCO

Date of Incident : 02 Mar 2015 RGMO Response

Time Grid Freq

Unit-4 Load

Unit-5

Load

Unit-6 Load

Unit-7 Load

Unit-4 Unit-5 Unit-6 Unit-7 Total

6:45:00 50.00 516.5 512.2 515.4 516.7

6:46:00 50.07 515.0 511.6 515.9 515.6

6:47:00 50.06 517.1 511.8 515.6 513.5

6:48:00 50.02 516.7 511.7 517.8 513.4

6:49:00 49.98 517.2 513.8 518.4 512.9

6:50:00 49.85 517.0 515.2 521.1 516.4 -0.2 1.5 2.7 3.5 7.5

6:51:00 49.76 516.2 516.0 520.0 515.8 -0.7 0.8 -1.1 -0.6 -1.6

6:52:00 49.74 516.4 515.9 520.9 515.9 0.2 -0.1 0.9 0.1 1.1

6:53:00 49.71 515.2 516.7 520.4 518.1 -1.2 0.8 -0.5 2.2 1.3

6:54:00 49.69 512.5 516.9 519.4 519.5 -2.7 0.2 -1.0 1.4 -2.1

6:55:00 49.68 510.4 516.9 519.3 520.5

6:56:00 49.68 511.5 516.5 518.9 521.6 As against 100 MW, only 7.5 MW received. 6:57:00 49.70 510.2 517.0 517.9 522.5

6:58:00 49.72 511.0 516.4 518.0 521.6

6:59:00 49.77 506.7 516.3 517.6 520.7

7:00:00 49.82 509.4 516.5 516.9 520.5

7:01:00 49.87 517.7 515.7 516.3 521.3

U4 & U7

w/o RF Hunting

U5 & U6

with RF Capturing

?????


Incidents identification –

xxxxxxx

750 MW










RGMO

Performance

OK

Not OK



TG response

100% Responsibility

with GU only

NCTPS, TANGEDCO

750 MW

NCTPS, TANGEDCO



For older machines, the CMC services are not available and this

facility will be made after renovation and Modernisation of obsolete

control systems. Most of the power plants served for more than

twenty years are already in the process of going towards the

latest Digital Control System. Boiler loadings will be varied by

CMC for extending the sustainability of RGMO response.

Thermal reserve available in the boiler only shall have to be utilised

as RGMO and for sustainability.

In RGMO also, if attempted without boiler firing change the pressure

deviation forces to reset the output change quickly. Sustainability

depends on the operator’s performance over the process in

older plants.

Honeywell’s Digital Control System of 1980’s design is working in

NCTPS for the last 21 years.

750 MW

Unit

No.

Unit Capacity

(MW)

Date of

commissioning

Boiler / Turbine

make

1 210 25.10.1994 BHEL/KWU

2 210 27.03.1995 BHEL/KWU

3 210 24.02.1996 BHEL/KWU

Honeywell’s Digital Control System of 1980’s design is

working in NCTPS for the last 21 years.

NCTPS, TANGEDCO

750 MW

Boiler

A path- ILS 1

5 6 7 8

Boiler

B path- ILS 2

5 6 7 8

Turbine

A path- ILS 4

9 10 11 12

Turbine

B path- ILS 5

9 10 11 12

Turbine

C path- ILS 6

1 2 3 4

AMC Boxes

1 2 3 4

AMC Boxes

5 6 7

AMC Boxes

1 2 3 4

AMC Boxes

5 6 7 8

HG 3 HG 4 HG 2 HG 1

HLPIU - 1 HLPIU - 2

9 10 11 12 1 2 3 4

US 5 US 6 US 7 US 8 US 4 US 3 US 2 US 1 HM AM

Data highway

A B

LCN A

LCN B

Architecture of Honeywell’s TDC 3000 System at NCTPS

PCIM

Electrical

System- ILS 3

9 10 11 12

NCTPS, TANGEDCO

750 MW

First declaration by Honweywell on obsoleteness

for this proprietary communication based DCS

was in 2006.

Subsequently most of the electronic modules

have been declared in the succeeding years.

The current situation on obsoleteness of

this system modules have been rounded

in the architecture NCTPS, TANGEDCO

750 MW

Boiler

A path- ILS 1

5 6 7 8

Boiler

B path- ILS 2

5 6 7 8

Turbine

A path- ILS 4

9 10 11 12

Turbine

B path- ILS 5

9 10 11 12

Turbine

C path- ILS 6

1 2 3 4

AMC Boxes

1 2 3 4

AMC Boxes

5 6 7

AMC Boxes

1 2 3 4

AMC Boxes

5 6 7 8

HG 3 HG 4 HG 2 HG 1

HLPIU - 1 HLPIU - 2

9 10 11 12 1 2 3 4


Data highway

A B

LCN A

LCN B

Annexure – II Obsolete items Honeywell’s TDC 3000 System at NCTPS

PCIM

Electrical

System- ILS 3

9 10 11 12

I/O rack

PS modules

Printers

UAIM

modules

Processor

modules

Processor

modules

19 nos. of K2LCN modules

Processor & UDM

modules

NCTPS, TANGEDCO

750 MW

Boiler

A path- ILS 1

5 6 7 8

Boiler

B path- ILS 2

5 6 7 8

Turbine

A path- ILS 4

9 10 11 12

Turbine

B path- ILS 5

9 10 11 12

Turbine

C path- ILS 6

1 2 3 4

AMC Boxes

1 2 3 4

AMC Boxes

5 6 7

AMC Boxes

1 2 3 4

AMC Boxes

5 6 7 8

HG 3 HG 4 HG 2 HG 1

HLPIU - 1 HLPIU - 2

9 10 11 12 1 2 3 4


Data highway

A B

LCN A

LCN B

Annexure – II Obsolete items Honeywell’s TDC 3000 System at NCTPS

PCIM

Electrical

System- ILS 3

9 10 11 12

I/O rack

PS modules

Printers

UAIM

modules

Processor

modules

Processor

modules

19 nos. of K2LCN modules

Processor & UDM

modules

Still the system is in our control

NCTPS, TANGEDCO

750 MW

North Chennai Thermal power Station, 3 x 210 MW Units TANGEDCO

Date Time Freuency Unit 1 Unit 2 Unit 3 Total Response

& %

01-Nov-14 02:15:00 49.9 158 200 155

01-Nov-14 02:16:00 49.92 157 200 155

01-Nov-14 02:17:00 49.93 157 201 155

01-Nov-14 02:18:00 49.95 157 201 154

01-Nov-14 02:19:00 49.96 157 201 153 511

01-Nov-14 02:20:00 49.86 168 209 160 537 26

01-Nov-14 02:21:00 49.87 162 208 160 5.0901-Nov-14 02:22:00 49.85 159 203 157

01-Nov-14 02:23:00 49.85 158 201 152

01-Nov-14 02:24:00 49.87 158 199 152

Generation in MW

Minute values of Generation



Not restored to original level due to Boiler’s large time constant NCTPS, TANGEDCO

%

750 MW

NCTPS, TANGEDCO

49.84

49.86

49.88

49.9

49.92

49.94

49.96

49.98

02:1

8:1

8

02:1

8:3

3

02:1

8:4

8

02:1

9:0

3

02:1

9:1

8

02:1

9:3

3

02:1

9:4

8

02:2

0:0

3

02:2

0:1

8

02:2

0:3

3

02:2

0:4

8

02:2

1:0

3

02:2

1:1

8

02:2

1:3

3

02:2

1:4

8

02:2

2:0

3

02:2

2:1

8

02:2

2:3

3

02:2

2:4

8

02:2

3:0

3

02:2

3:1

8

02:2

3:3

3

02:2

3:4

8

02:2

4:0

3

02:2

4:1

8

02:2

4:3

3

02:2

4:4

8

02:2

5:0

3

02:2

5:1

8

02:2

5:3

3

02:2

5:4

8

02:2

6:0

3

02:2

6:1

8

02:2

6:3

3

Fre

qu

en

cy H

z

Time

Frequency variation 1 Nov 2014

150

160

170

180

190

200

210

02:1

8:18

02:1

8:33

02:1

8:48

02:1

9:03

02:1

9:18

02:1

9:33

02:1

9:48

02:2

0:03

02:2

0:18

02:2

0:33

02:2

0:48

02:2

1:03

02:2

1:18

02:2

1:33

02:2

1:48

02:2

2:03

02:2

2:18

02:2

2:33

02:2

2:48

02:2

3:03

02:2

3:18

02:2

3:33

02:2

3:48

02:2

4:03

02:2

4:18

02:2

4:33

02:2

4:48

02:2

5:03

02:2

5:18

02:2

5:33

02:2

5:48

02:2

6:03

02:2

6:18

02:2

6:33

MW

Time



Continued process response - GU

NCTPS, TANGEDCO

750 MW

NCTPS, TANGEDCO

150

160

170

180

190

200

210

02:1

8:1

8

02:1

8:3

3

02:1

8:4

8

02:1

9:0

3

02:1

9:1

8

02:1

9:3

3

02:1

9:4

8

02:2

0:0

3

02:2

0:1

8

02:2

0:3

3

02:2

0:4

8

02:2

1:0

3

02:2

1:1

8

02:2

1:3

3

02:2

1:4

8

02:2

2:0

3

02:2

2:1

8

02:2

2:3

3

02:2

2:4

8

02:2

3:0

3

02:2

3:1

8

02:2

3:3

3

02:2

3:4

8

02:2

4:0

3

02:2

4:1

8

02:2

4:3

3

02:2

4:4

8

02:2

5:0

3

02:2

5:1

8

02:2

5:3

3

02:2

5:4

8

02:2

6:0

3

02:2

6:1

8

02:2

6:3

3

MW

Time



Continued process response - GU

Fall occur at Fourth or fifth minute

750 MW

NCTPS, TANGEDCO

49.6

49.65

49.7

49.75

49.8

49.85

49.9

49.95

50

12:1

5:48

12:1

6:10

12:1

6:32

12:1

6:54

12:1

7:16

12:1

7:38

12:1

8:00

12:1

8:22

12:1

8:44

12:1

9:06

12:1

9:28

12:1

9:50

12:2

0:12

12:2

0:34

12:2

0:56

12:2

1:18

12:2

1:40

12:2

2:02

12:2

2:24

12:2

2:46

12:2

3:08

12:2

3:30

12:2

3:52

12:2

4:14

12:2

4:36

12:2

4:58

12:2

5:20

12:2

5:42

Freq

uenc

y H

z

Time


170

175

180

185

190

195

200

205

210

215

220

12:1

5:48

12:1

6:09

12:1

6:30

12:1

6:51

12:1

7:12

12:1

7:33

12:1

7:54

12:1

8:15

12:1

8:36

12:1

8:57

12:1

9:18

12:1

9:39

12:2

0:00

12:2

0:21

12:2

0:42

12:2

1:03

12:2

1:24

12:2

1:45

12:2

2:06

12:2

2:27

12:2

2:48

12:2

3:09

12:2

3:30

12:2

3:51

12:2

4:12

12:2

4:33

12:2

4:54

12:2

5:15

12:2

5:36

MW

Time



Continued process response - GU 750 MW

NCTPS, TANGEDCO

170

175

180

185

190

195

200

205

210

215

220

12:1

5:4

8

12:1

6:0

9

12:1

6:3

0

12:1

6:5

1

12:1

7:1

2

12:1

7:3

3

12:1

7:5

4

12:1

8:1

5

12:1

8:3

6

12:1

8:5

7

12:1

9:1

8

12:1

9:3

9

12:2

0:0

0

12:2

0:2

1

12:2

0:4

2

12:2

1:0

3

12:2

1:2

4

12:2

1:4

5

12:2

2:0

6

12:2

2:2

7

12:2

2:4

8

12:2

3:0

9

12:2

3:3

0

12:2

3:5

1

12:2

4:1

2

12:2

4:3

3

12:2

4:5

4

12:2

5:1

5

12:2

5:3

6

MW

Time



Continued process response - GU 750 MW

NCTPS, TANGEDCO

Turbine Control System


Pressure correction Revising

the set point Automatically

at RGMO incident.

Load limiter

Frequency Influence

Frequency switch

On/Off

750 MW

NCTPS, TANGEDCO


150

160

170

180

190

200

210

2:18:18

2:18:33

2:18:48

2:19:03

2:19:18

2:19:33

2:19:48

2:20:03

2:20:18

2:20:33

2:20:48

2:21:03

2:21:18

2:21:33

2:21:48

2:22:03

2:22:18

2:22:33

2:22:48

2:23:03

2:23:18

2:23:33

2:23:48

2:24:03

2:24:18

2:24:33

2:24:48

2:25:03

2:25:18

2:25:33

2:25:48

2:26:03

2:26:18

2:26:33

Time

MW


This sustainability we obtained

via changing the throttle pressure set point

by -2 KSC or +2 KSC automatically

at the time RGMO incident

750 MW

NCTPS, TANGEDCO



Newly commissioned machines having CMC control,

for the same RGMO output, we noticed the

sustainability is different which may be due to

variation in the process parameters.

Two 500 MW Units of NTECL, Vallur who lead

2nd Mar 2015 incident have been taken

as case study.

750 MW

NCTPS, TANGEDCO

500 MW Unit 1 of NTECL, Vallur

RGMO Response 339 MW to 355 MW 16 MW


Frequency

MW


9 MW

750 MW

NCTPS, TANGEDCO RGMO Response 356 MW to 372 MW 16 MW

500 MW Unit 2 of NTECL, Vallur

Frequency

MW


Continued process response - Generating Units 750 MW

Full load with Valve wide-open – Commercial advantages

Mill loading maximised – Full/partial generation – Mills under

vibration

Calorific value of coal – Partial/full load


NCTPS, TANGEDCO

750 MW

Methodology for the machines running always with 105% generation.

Whether RGMO response will be zero in these machines.???

Restricting the generating units from running with wider open of control

valves for maximising the RGMO response to the electrical grid.

SRPC - Categorization of Performance

Descriptions Used ( Expected Response is taken as 5% of Installed Capacity)

Sl No Response

Code Description Explanation

1 R Responded Response Greater than 70% of Expected

response is achieved

2 PR Partially

Responding

Response 30 to 70 % of Expected response is

achieved

3 IR Insufficient

Response

Response less than 30% of Expected


4 NR No Response No Change in Generation

5 RR Reverse

Response

Generator acts against the RGMO/FGMO

feature. i.e when frequency dips , generation

also reduces & vice versa


NCTPS, TANGEDCO

750 MW

NCTPS, TANGEDCO

From Nov 2014 to Mar 2015

Not capturing at higher frequency

Elevated f measurement

Load limiter

Lower target Lower target

750 MW

NCTPS, TANGEDCO

To sustain the primary response for longer time (3-5 minutes) and not

to fall below the original generation to assist secondary control. This can

be utilised in the period of initialisation of secondary control.

One we show the performance to the grid and then we shall request

SRLDC to modify the response limts. i.e. 50-60% as against 70% of

expected generation via RGMO shall be considered as RGMO responded.

Making as achievable target by individual unit.

On 02 Mar 2015 incident, SR response was 159 MW (21.37%)

as against the target of 744 MW. National demand??????

In order to achieve the expected average demand of 4000-6000 MW/Hz as

primary response in the grid at the National level,

The number of thermal machines on bar is 66 Nos during this incident.

The MW achieved per machines is 2.40 MW as against

the target of 11.27 MW per machine. Improvement in RGMO response from Generating units will be more.

The number of successful units will definitely be more and the performance

sustainability with prolonged available thermal reserve in the boiler will also

be achieved

Continued process response - Generating Units 750 MW

NCTPS, TANGEDCO

Date Freq.

variation

Delta

f

RGMO Expected

Actual RGMO

% Achieved

Frequency dip

07 04 2015 883.41 159.24 18.03

26.06.2015 638.69 23.52 3.68

28.07.2015 714.34 118.45 16.58

19.08.2015 50 to 49.86 0.14 4000 *14 =560 750.48 157.32 20.96

34.2%

04.09.2015 725.72 148.154 20.41

Frequency raise

25.04.2015 -754.35 -76.16 10.1

26.04.2015 -726.31 -153.23 21.1

26.05.2015 50 to 50.2 0.2 4000 *.2 =800 -822.89 -237.81 28.9

34.0%


Courtesy: SRLDC

750 MW

This is excluding Hydro 100 MW

Request to SRPC

Revise the Categorization of Performance

Descriptions Used ( Expected Response is taken as 5% of Installed Capacity)

Sl No Response

Code Description Explanation

1 R Responded Response Greater than 50% of Expected


2 PR Partially

Responding

Response 30 to 50 % of Expected response

is achieved

3 IR Insufficient

Response

Response less than 30% of Expected


4 NR No Response No Change in Generation

5 RR Reverse

Response

Generator acts against the RGMO/FGMO

feature. i.e when frequency dips , generation

also reduces & vice versa


NCTPS, TANGEDCO

70%

30% to 70%

750 MW










RGMO

Performance

OK

Not OK



TG response

100% Responsibility

with GU only

NCTPS, TANGEDCO

750 MW

NCTPS, TANGEDCO

26.06.15

Analysis

Neyveli TS II 5 210 RGMO 220.3 218.64 104.91 0.19 -1.67 RR

Neyveli TS II 5 210 RGMO 220.3 218.64 104.91 0.19 -1.67 RR

28.07.2015 Analysis

Neyveli TS II 5 210 217.8 218.64 103.72 2.69 0.83 30.86 PARTIAL RESPONSE

Neyveli TS II 5 210 217.8 218.64 103.72 2.69 0.83 30.86 PARTIAL RESPONSE

Vijaywada

TPS 5 210 120 120 57.143 6 0 0 NO RESPONSE

Vijaywada

TPS 5 210 120 120 57.143 6 0 0 NO RESPONSE

If Neyveli generates 1.5 MW excess then responded

Since 70% is considered as RESPONDED

>30% only will have to be relived in calcuating the RGMO target.

Analysis - Generating Units & SRLDC Case I Less target

Case ii & should be no target

NCTPS, TANGEDCO

RGMO Analysis 26.05.2015

Neyveli TS II

5 210 217.81 210.28 103.719 10.89 -7.53 -69.15 PARTIAL

RESPONSE

5 210 217.81 203.6 103.719 10.89 -14.21 -130.49 RESPONDED

6 210 206.11 202.76 98.14762 10.31 -3.35 -32.49 PARTIAL

RESPONSE

6 210 206.11 197.75 98.14762 10.31 -8.36 -81.09 RESPONDED

7 210 217.54 210.02 103.5905 10.88 -7.52 -69.12 PARTIAL

RESPONSE

7 210 217.54 205.84 103.5905 10.88 -11.7 -107.54 RESPONDED

North Chennai

TPS

1 210 215.78 212.51 102.7524 10.79 -3.27 -30.31 PARTIAL

RESPONSE

1 210 215.78 212.51 102.7524 10.79 -3.27 -30.31 PARTIAL

RESPONSE

2 210 212.08 210.36 100.9905 10.6 -1.72 -16.23 INSUFFICIENT

RESPONSE

2 210 212.08 210.36 100.9905 10.6 -1.72 -16.23 INSUFFICIENT

RESPONSE

3 210 219.87 200.33 104.7 10.99 -19.54 -177.8 PARTIAL

RESPONSE

3 210 219.87 204.27 104.7 10.99 -15.6 -141.95 RESPONDED


> 10.5 MW

High response,

recorded as partial response

More target

NCTPS, TANGEDCO

25.04.2015 Analysis

Neyveli TS II 5 210 217 212 103.32 3.53 -5.01 RESPONDED

Neyveli TS II 5 210 217 202.8 103.32 3.53 -14.2 RESPONDED

Ramagunda

m 6 500 508.6 508.6 101.73 16.37 0 NO RESPONSE

Ramagunda

m 6 500 508.6 506.3 101.73 16.37 -2.35

INSUFFICIENT

RESPONSE

07.04.15

Analysis

Ramagundam 7 500 514.5 517.4 102.9 10.51 2.93 27.9 INSUFFICIENT

RESPONSE

Ramagundam 7 500 514.5 516.2 102.9 10.51 1.75 16.7 INSUFFICIENT

RESPONSE

Analysis - Generating Units & SRLDC Already higher generation

Reduced target fixed

Formula to be modified.

This shall

be 33 MW

Or 25 MW

This shall

be 17 MW

Or 10.5 MW

NCTPS, TANGEDCO

26.04.2015

Analysis

Neyveli TS II 5 210 215.3 210.28 102.52 5.2 -5.02 RESPONDED

Neyveli TS II 5 210 215.3 205.27 102.52 5.2 -10.03 RESPONDED


This shall

be 17 MW

Or 10.5 MW










RGMO

Performance

OK

Not OK



TG response

100% Responsibility

with GU only

NCTPS, TANGEDCO

750 MW

In general 1 minute data is being studied at State LDC and

SRLDC, Bangalore.

Collection of 1 second data from all the generating

stations

After getting RGMO performance closer to the our target,

For large variation of frequency incidents,

Frequency containment results arriving out of Primary

response and the frequency trend patterns for different

case studies to be studied with 1 second data. Some

examples are given here of course with lesser RGMO

performance.



NCTPS, TANGEDCO

750 MW

NCTPS, TANGEDCO


Response % Achieved

Frequency dip

07 04 2015 883.41 159.24 18.03

26.06.2015 638.69 23.52 3.68

28.07.2015 714.34 118.45 16.58

19.08.2015 750.48 157.32 20.96

04.09.2015 725.72 148.154 20.41

Frequency raise

25.04.2015 -754.35 -76.16 10.1

26.04.2015 -726.31 -153.23 21.1

26.05.2015 -822.89 -237.81 28.9


Courtesy: SRLDC

750 MW

NCTPS, TANGEDCO

Analysis 750 MW 19th August 2015

Freq. Variation

MW – Unit 3 NCTPS TANGEDCO

NCTPS, TANGEDCO

Analysis 750 MW 26th May 2015

Freq. Variation

MW – Unit 3 NCTPS TANGEDCO

NCTPS, TANGEDCO

49.84

49.86

49.88

49.9

49.92

49.94

49.96

49.98

02:1

8:1

8

02:1

8:3

3

02:1

8:4

8

02:1

9:0

3

02:1

9:1

8

02:1

9:3

3

02:1

9:4

8

02:2

0:0

3

02:2

0:1

8

02:2

0:3

3

02:2

0:4

8

02:2

1:0

3

02:2

1:1

8

02:2

1:3

3

02:2

1:4

8

02:2

2:0

3

02:2

2:1

8

02:2

2:3

3

02:2

2:4

8

02:2

3:0

3

02:2

3:1

8

02:2

3:3

3

02:2

3:4

8

02:2

4:0

3

02:2

4:1

8

02:2

4:3

3

02:2

4:4

8

02:2

5:0

3

02:2

5:1

8

02:2

5:3

3

02:2

5:4

8

02:2

6:0

3

02:2

6:1

8

02:2

6:3

3

Fre

qu

en

cy H

z

Time


150

160

170

180

190

200

210

02:1

8:18

02:1

8:33

02:1

8:48

02:1

9:03

02:1

9:18

02:1

9:33

02:1

9:48

02:2

0:03

02:2

0:18

02:2

0:33

02:2

0:48

02:2

1:03

02:2

1:18

02:2

1:33

02:2

1:48

02:2

2:03

02:2

2:18

02:2

2:33

02:2

2:48

02:2

3:03

02:2

3:18

02:2

3:33

02:2

3:48

02:2

4:03

02:2

4:18

02:2

4:33

02:2

4:48

02:2

5:03

02:2

5:18

02:2

5:33

02:2

5:48

02:2

6:03

02:2

6:18

02:2

6:33

MW

Time



26 MW Analysis

NCTPS, TANGEDCO

750 MW

NCTPS, TANGEDCO

49.96

49.98

50

50.02

50.04

50.06

50.08

50.1

10:2

8:18

10:2

8:36

10:2

8:54

10:2

9:12

10:2

9:30

10:2

9:48

10:3

0:06

10:3

0:24

10:3

0:42

10:3

1:00

10:3

1:18

10:3

1:36

10:3

1:54

10:3

2:12

10:3

2:30

10:3

2:48

10:3

3:06

10:3

3:24

10:3

3:42

10:3

4:00

10:3

4:18

10:3

4:36

10:3

4:54

10:3

5:12

10:3

5:30

10:3

5:48

10:3

6:06

10:3

6:24

Freq

uenc

y H

z

Time


165

170

175

180

185

190

195

200

205

MW

Time



15 MW Analysis

NCTPS, TANGEDCO

750 MW

NCTPS, TANGEDCO

49.6

49.65

49.7

49.75

49.8

49.85

49.9

49.95

50

12:1

5:48

12:1

6:10

12:1

6:32

12:1

6:54

12:1

7:16

12:1

7:38

12:1

8:00

12:1

8:22

12:1

8:44

12:1

9:06

12:1

9:28

12:1

9:50

12:2

0:12

12:2

0:34

12:2

0:56

12:2

1:18

12:2

1:40

12:2

2:02

12:2

2:24

12:2

2:46

12:2

3:08

12:2

3:30

12:2

3:52

12:2

4:14

12:2

4:36

12:2

4:58

12:2

5:20

12:2

5:42

Freq

uenc

y H

z

Time


170

175

180

185

190

195

200

205

210

215

220

12:1

5:48

12:1

6:09

12:1

6:30

12:1

6:51

12:1

7:12

12:1

7:33

12:1

7:54

12:1

8:15

12:1

8:36

12:1

8:57

12:1

9:18

12:1

9:39

12:2

0:00

12:2

0:21

12:2

0:42

12:2

1:03

12:2

1:24

12:2

1:45

12:2

2:06

12:2

2:27

12:2

2:48

12:2

3:09

12:2

3:30

12:2

3:51

12:2

4:12

12:2

4:33

12:2

4:54

12:2

5:15

12:2

5:36

MW

Time



28 MW Analysis 750 MW

NCTPS, TANGEDCO

49.96

49.98

50

50.02

50.04

50.06

50.08

50.1

50.12

10:0

2:46

10:0

2:58

10:0

3:10

10:0

3:22

10:0

3:34

10:0

3:46

10:0

3:58

10:0

4:10

10:0

4:22

10:0

4:34

10:0

4:46

10:0

4:58

10:0

5:10

10:0

5:22

10:0

5:34

10:0

5:46

10:0

5:58

10:0

6:10

10:0

6:22

10:0

6:34

10:0

6:46

10:0

6:58

10:0

7:10

10:0

7:22

10:0

7:34

10:0

7:46

10:0

7:58

10:0

8:10

10:0

8:22

10:0

8:34

10:0

8:46

10:0

8:58

Frqu

ency

Hz

Time

Frequency Variation 16 Dec 2014

192

194

196

198

200

202

204

206

208

210

212

NCTPS Responses - 3 x 210 MW Units 16 Dec 2014 (Unit 3 TM 140 MW)

Unit 1 Unit 2

24 MW Analysis

NCTPS, TANGEDCO

750 MW



RGMO incident – The quantum of loss / gain of MW in

the grid is to be known to the Generating stations.

Analysis will be based on this quantum requirement only.

To check whether RGMO is meeting the actual demand

of the grid due to disturbance.

NCTPS, TANGEDCO

750 MW



For larger frequency variations, the disturbed grid with

intrusion of RGMO generation shall be mathematically

modeled and the simulation results shall be arrived at

of course with minimum assumptions.

NCTPS, TANGEDCO

750 MW

In general 1 minute/10 second data is being studied at

State LDC and SRLDC, Bangalore.

Collection of 1 second data from all the generating

stations

Frequency containment results arriving out of Primary

response and frequency trend patterns for different

case studies to be studied with 1 second data.

Under max. RGMO performance, this frequency pattern

study will be effective for deciding methodologies on

secondary control.


NCTPS, TANGEDCO

750 MW










RGMO

Performance

OK

Not OK



TG response

100% Responsibility

with GU only

NCTPS, TANGEDCO

750 MW

NCTPS, TANGEDCO

Error free Consistent RGMO performance require study

on various case studies and process parameters for non

performing machines.

In order to achieve the expected average demand of 600-750 MW as

primary response in the Southern grid,

To study the various RGMO case studies, the patterns of frequency

variation for RGMO behaviour, RGMO implementation problems and

suggestions/solutions/improvements for reducing the shortfall in

RGMO behaviour against our primary response target.

Knowledge transfer on RGMO among the constituents is very vital.



750 MW

NCTPS, TANGEDCO






& again consistency







750 MW

Regional Power Committee RPC

Regional Load Dispatch Centre RLDC

State Load Dispatch Centre LDC

Generating station

Hon’ble CERC

& others

NCTPS, TANGEDCO

750 MW










RGMO

Performance

OK

Not OK



TG response

100% Responsibility

with GU only

NCTPS, TANGEDCO

750 MW




TG response - Generating Units

Analysis - Generating Units & SRLDC RGMO

Performance

OK

Not OK



NCTPS, TANGEDCO

Minimising the lags

750 MW

Unknown is Ocean

Known is Drop

For having given the oppurtunity to share

our experience and travel in FGMO/RGMO

for more than a decade

For making GU as Member in the process of

fine tuning the FGMO/RGMO performance

of our Generating units to serve to our Country

NCTPS, TANGEDCO

Let us aim for

2% error in each RGMO sub activity, successful rate will be (0.98)3 = 0.9411

[email protected]

+91 9445856639

750 MW

mailto:[email protected]

NCTPS, TANGEDCO

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