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Subject: 34th meeting of Northern Regional Power Committee and 30th meeting of TCCAgenda.

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The 34th meeting of Northern Regional Power Committee (NRPC) will be held at 1000 Hrs on 20th March, 2015 at Hotel Namah, Jim Corbett National Park, Uttarakhand. NRPC meeting shall be preceded by 30th meeting of Technical Coordination Sub-committee (TCC) at 1000 Hrs on 19th March,

2015 at the same venue. Agenda for the meetings is attached herewith.

~/Yours faithfully,

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(P.S. Mhaske)

~~ Member Secretary

NORTHERN REGIONAL POWER COMMITTEE

AGENDA FOR

30th MEETING OF TECHNICAL COORDINATION SUB-COMMITTEE &

34th MEETING OF NORTHERN REGIONAL POWER COMMITTEE

Time & Date of TCC meeting : 10:00 Hrs. on 19.03.2015 Time & Date of NRPC meeting : 10.00 Hrs. on 20.03.2015 Venue: Hotel Namah, Jim Corbett National Park, Uttarakhand

C O N F I R M A T I O N O F M I N U T E S ( T C C )

A.1 Minutes of 29th meeting of TCC

Minutes of 29th meeting of TCC & 33rd meeting of NRPC held on 10th and 11th November, 2014 respectively, were circulated vide letter No. NRPC/Comml/209/RPC (33rd)/2014/7549-7640 dated 24th December, 2014. No comments have been received on the minutes. TCC may confirm the minutes.

C O N F I R M A T I O N O F M I N U T E S ( N R P C )

A.2 Minutes of 33rd meeting of NRPC Minutes of 29th meeting of TCC & 33rd meeting of NRPC held on 10th and 11th November, 2014 respectively, were circulated vide letter No. NRPC/Comml/209/RPC (33rd)/2014/7549-7640 dated 24th December, 2014. No comments have been received on the minutes.

NRPC may confirm the minutes.

O P E R A T I O N A L I S S U E S B.1 PSS tuning

In the 27th TCC/30th NRPC meeting it was decided to constitute a group to analyze the data of PSS tuning received from various generating stations and make suitable recommendations with regard to PSS tuning. The recommendations of the group

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30th TCC & 34th NRPC Meetings (19th and 20th March, 2015) – Agenda

were discussed in the aforesaid meetings and following guidelines were agreed regarding PSS tuning:

a. All generating units with capacity over 50 MW, for which PSS have not been tuned or Step Response Test has not been carried out during last 12 months, should do so within next 12 months and submit to NRPC, NRLDC and CTU, the results of the Step Response Test.

b. If PSS has been tuned or Step Response Test has been carried out during last 12 months, the generating company should submit to NRPC, NRLDC and CTU, the results of the Step Response Test within one month.

c. If results of Step Response Test indicate sufficient damping, generating company would performed next Step Test after three year or at the time of major overhauling of the machine, whichever will be earlier.

d. Generating Companies would arrange for re-tuning of PSS, if Step Response Test indicates insufficient damping or oscillations.

e. All new units with capacity over 50 MW must carry out PSS tuning before declaration of Date of Commercial Operation (COD). A report along with model parameters shall be submitted to CTU, RLDC/SLDC and NRPC for taking the correct modelling in the system study software (s).

f. NRLDC will observe and analyze the changing grid conditions based on the output of PMUs and will inform the generating Company concerned if oscillations are observed. On receipt of the information, the generating company would arrange for re-tuning of PSS within 3 months.

g. In some of the generating units it may not be feasible to tune PSS. Generating Companies would furnish details of such units (Year of Commercial operation, capacity, OEM, reason as to why PSS cannot be tuned etc), which in their opinion are not amenable to PSS tuning. These would then be discussed in the OCC and TCC/NRPC. In cases where there is general agreement that it may not be feasible to carry out PSS tuning, the matter may be taken to CERC for seeking exemption.

Accordingly, in the 106th OCC meeting held in December 2014 members of the OCC were requested to submit the details of PSS tuning done or Step Response Test carried out since 01.11.2013 on their generating units with capacity over 50 MW along with the results of the Step Response Test to NRPC, NRLDC and CTU. Members were also requested to intimate their programme of arranging PSS tuning or Step Response Test on their generating units with capacity over 50 MW, if not done since 01.11.2013 to 31.10.2014.

The information available so far in the NRPC Secretariat has been complied and is enclosed at Annex-I. Following may be observed from the aforesaid information:

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Utility Total

Units (>50 MW)

Units for which full or partial information has been submitted

Number of Units for which no information has been submitted.

Units on which Digital AVR provided

Units on which Step Test is required to be carried out before October 2015

Units for which test has been carried out but results have to be submitted

Units for which incomplete information has been submitted

NTPC 52 31 25 6 - - NPCIL 7 - - - - 7 NHPC 33 9 2 - 7 24 BBMB 22 5 5 - 5 - UPRVUNL 24 17 12 - 2 1 RRVUNL 25 14 - 6 8 10 JSW (Rajwest Power)

8 - - - - 8

Adani Power Ltd (Kawai TPS)

2 - - - - 2

SJVN 12 12 - - 11 1 THDC 8 - - - - 8 ADHPL(Allain Duhangan)

2 2 - - - 2

APCPL(IGSTPP)

3 - - - - 3

CLP, Jhajjar 2 - - - - 2 NLC 2 - - - - 2 PSPCL 14 - - - - 14 IPGCL 2 - - - - 2 PPCL(Pragati)

9 - - - - 9

HPGCL 12 - - - - 12 ROSA TPS 4 - - - - 4 ANPARA-C(LANCO)

2 - - - - 2

Following is proposed:

i. Units for which information has not been submitted so far, the same should be

submitted by 31.03.2015 to NRLDC and NRPC Secretariat. Similarly, units for which complete information has not been made available as may be seen from Annex-I), the same should be submitted by 31.03.2015. SLDCs are requested to obtain information from IPPs in their domain for submission to NRPC & NRLDC.

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ii. Generating units for which Step test/PSS tuning has not been carried out after 01.11.2013, the step test is to be carried out by October 2015 in line with above guidelines approved in the last NRPC meeting. Utilities may plan for the same and intimate schedule of tests to NRLDC and NRPC Secretariat.

iii. Units for which step test/PSS tuning has been carried out after 01.11.2013, results of the tests should be submitted to NRLDC and NRPC Secretariat, if not submitted earlier.

iv. Generating companies should plan for retrofitting of units having analog AVR with Digital AVR and indicate timeframe for the same.

Members may deliberate. B.2 Fiber Optic based communication system in Northern region

A project for implementation of Fiber Optic based communication system in Northern region to connect central sector substations and power plants was approved in the 18th NRPC meeting held on 27th November, 2010. The requirement of the constituents was also to be included and the requirement of physical path redundancy was also expressed. It was also decided that all the upcoming power plants and substations of central sector shall be connected on Fiber Optic based communication system. To complete the network, around 1300 Kms. of existing fiber optic network of POWERGRID Telecom was also to be used. Following OPGW requirements had been incorporated under this project: Central Sector - 4489 Kms BBMB - 211Kms (as modified in 29th NRPC Meeting) PSTCL - 210 Kms HPSEB - 352Kms UPPTCL - 368Kms (as modified in 29th NRPC Meeting) DTL - 286 Kms In respect of Central Sector portion, POWERGRID had informed in the 27th NRPC meeting held on 30th November, 2012 that the work had been awarded to M/s KEC with the completion schedule of 18 months and the execution was in progress. In the 33rd NRPC meeting held on 11th November, 2014,POWERGRID had intimated that 2450 kms (54.58%) of OPGW installation had been completed in case of Central Sector and remaining 2039 kms would be completed by March, 2015. completed OPGW installation included 198 kms out of 211 kms for BBMB.

NHPC has been raising this issue of OPGW connectivity of its power plants and has been constantly following it up with POWERGRID/NRPC. It has almost been a year since then. NHPC has contended that as on date, not a single NHPC power station in NR is connected on OPGW. They have further mentioned that POWERGRID has time and again shifted the completion target dates. Further, in the 4thTeST meeting held on 6th Feb 2015, POWERGRID had informed that Dhauliganga & Chamera

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Pooling Stations were likely to be completed by March, 2015 and the overall completion date was likely to be June, 2015.

NHPC has requested POWERGRID to provide station wise completion schedule of the OPGW project in respect of all the NHPC power stations for completion by March 2015, status of implementation of the OPGW project, as on date and likely completion date in respect of NHPC power stations in NR.

SJVN Ltd has requested POWERGRID to implement the OPGW link between Nalagarh and RHEP for data & voice communication at the earliest.

POWERGRID is requested to complete the same at the earliest.

In respect of State Sector portion, POWERGRID had informed in the 28th NRPC meeting held on 26th April, 2013, that the bids were opened on 08.03.2013 but the work was not awarded. In the 29th NRPC meeting held on 13th September, 2013, POWERGRID had intimated that a special committee had been constituted to assess the bidders as awarding the work to those bidders who have already been awarded Central Sector work would hamper the execution of both portions. In the 30th NRPC meeting held on 28th February, 2014, POWERGRID had intimated that the work could not be awarded as the vendors who participated in the tendering process did not have the requisite capability since same gangs were to be used by all of them. As such, State’s portion would be re-tendered with NIT expected in March, 2014 and placement of LoA expected in June, 2014. In the 31st NRPC meeting held on 24thJuly, 2014, POWERGRID had intimated that bids were opened on 22nd July, 2014 and LoA was likely to be issued within next 02 months. In the 33rd NRPC meeting held on 11th November, 2014, POWERGRID had intimated thatbids were under evaluation and LoA was expected by December, 2014 with the completion schedule of 02 years thereafter.

In view of the importance of OPGW, Member Secretary, NRPC vide his letter dated 23.01.2015 had taken up the matter with CMD, POWERGRID expressing concern over delay in placing order for state sector portion. In response, GM, POWERGRID vide letter dated 20.02.2015 has informed that award was likely to be placed by early March 2015.

In the context of state portion, DTL has informed that their communication network operates on OPGW/OFC, PLCC & Radio system scattered on O/H lines and U/G cables. Presently OPGW has been laid on 220KV feeders lines which are of 12 fibres/cores. This OPGW at present is being utilized for real time data communication of Delhi SLDC and NRLDC and for operation of Delhi State Islanding Scheme. DTL shall also be utilising the OPGW for Protection and Metering purpose.

DTL has stated that in order to ensure reliable operation of Delhi Islanding Scheme all the substations are essentially to be connected through optical fibre for which the matter was also discussed in the second TeST Meeting held on 12-Aug 2014.

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POWERGRID was requested to expedite procurement and installation of OPGW for Delhi Islanding Scheme.

POWERGRID may update the status.

Members may deliberate.

B.3 ADDITIONAL OPGW CONNECTIVITY IN NORTHERN REGION UNDER FIBER OPTIC EXPANSION PROJECT. In the 28th NRPC meeting held on 26th April, 2013, additional OPWG connectivity for around 2285 Kms with the initial estimated cost of approximately Rs 55 Crs. was approved. This additional requirement was proposed to be awarded separately and the completion period was to be 24 months after award. However, BBMB, DTL, PSTCL and UPPTCL were to communicate the consent of their managements to POWERGRID for additional requirement.

In the 31st NRPC meeting held on 24th July, 2014, POWERGRID had intimated that all had confirmed the approval of their managements except DTL. DTL had confirmed that they did not have any additional requirement. POWERGRID had intimated that NIT had been floated for additional requirement and bidding process was expected to be completed by July’14.

In the 33rd NRPC meeting held on 11th November, 2014, POWERGRID had intimated that constituents’ requirements had been included in the project and LoA was expected by December, 2014 with the completion schedule of 02 years thereafter.


Members may deliberate. B.4 PROCEDURE FOR TRANSMISSION ELEMENTS OUTAGE PLANNING.

In accordance with regulatory provisions, responsibility of outage planning has been entrusted to RPC in consultation with NLDC and RLDC. Accordingly, the issue is deliberated in the monthly OCC meetings. The issue has gained importance after the twin grid disturbances in July 2012.

In order to standardize the process of outage planning, a draft Procedure for “Transmission Elements Outage Planning” was submitted by NLDC. The procedure was discussed in the OCC meeting and utilities were also requested to submit their comments on the draft proposed by NLDC.

Using the draft procedure submitted by NLDC as base and considering the comments received from utilities, the draft was revised by NRPC secretariat and was put up for discussion in the 106th meeting of OCC held in December 2014. OCC had agreed to the proposed procedure with certain amendments and recommended for the approval of TCC/NRPC.

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The Draft Procedure for “Transmission Elements Outage Planning” finalised by OCC is enclosed as Annex-II for the approval of TCC/NRPC.

TCC/NRPC may approve the procedure.

B.5 Overview of Grid Operation B.5.1 Highlights of grid operation

NRLDC would brief members about highlights of grid operation during December, 2014- February, 2015.

The actual Power Supply Position (PSP) for the period November, 2014 - February, 2015 is enclosed at Annex-III. Northern Region had a peak power shortage in the range of 3.8 to 6.2% and energy shortage in the range of 5.0-6.8%. J&K faced higher energy as well as peak shortages of the order of 20% and U.P also faced peak shortages (in the range of 3.2-16.1%).) and energy shortages (in the range of 12.9-17.1%). LGBR for the year 2015-16 is under preparation. SLDCs have been requested to submit their assessment about anticipated Power Supply Position (PSP) for April, 2015 to June, 2015. Members will be briefed about the same in the meeting. Members may deliberate measures for ensuring smooth grid operation.

B.5.2 Consumption Growth Pattern

During the last 12 months the consumption Growth pattern in the region is given at Annex-IV. It may be seen that Region had recorded highest consumption growth of 14.69 % during June, 2014.


B.6 Summer Preparedness in Northern Region (Agenda by NRLDC)

The Northern Region meets its peak demand during Summer/Monsoon months. Therefore, high line loadings and low voltages have been the traditional constraints in NR during these months. Further, during summer, dust storm/thunderstorm had also resulted in heavy load crash for limited time and collapse of transmission infrastructure at times. Load crashes for limited duration had thrown up operational challenges while transmission infrastructure had caused constraints in meeting loads/system security for extended time. The points related to Summer Preparedness have been discussed in 108th OCC meeting also.

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Following are the points to be taken care by every state utility:

a) For generation availability adequacy: • Proper assessment of load generation balance and arrangements under

STOA etc. • Expediting upcoming generation: Koldam, Talwandi Saboo, Kalisindh,

Goindwal Sahib. • Availability of existing units: Bhakra, Dehar, Uri-II station, Parichha,

Harduaganj, Obra etc. • Availability of fuel: Coal, Gas etc. • Proper and quick actions during load crash.

b) For transmission adequacy: • Pre Summer Maintenance of transmission lines, strengthening of towers etc. • Expediting upcoming transmission elements. • Assessment of ATC/TTC of individual state control areas • Mitigation of congestion transmission corridor where it was seen last year:

i) WR-NR corridor: a. Status of 765kV Gwalior-Jaipur line & Jaipur-Bhiwani line. b. Commissioning of Mohindergarh-Bhiwani D/C line for increasing

power order on HVDC Mundra-Mahendragarh bipole

ii) Import by Delhi: Status of identified planned network in Delhi: a. Uprating of ICTs at Bamnauli and Mandola (it would be better to

complete by April 2015 or otherwise giving shutdown may also be an issue),

b. New 220 kV lines from Mundka, Harsh Vihar, Maharani Bagh c. Uprating of transmission lines with HTLS conductor. d. Connectivity of 220 kV Gazipur-Patparganj e. Healthiness of 220 kV BTPS-Noida-Gazipur

iii) Import by Punjab:

a. Interconnection at Nakodar & Mukatsar station of Punjab Ring. b. Goindwal Sahib generation (since it is at 220 kV level)

iv) Import by Uttrakhand:

a. 400kV Bareilly-Kashipur-Roorkee D/C

v) Import by UP: a. TTC/ATC computed by UP SLDC in the range of 6500/6000 MW. b. Present allocation by UP from ISGS/LTA in this range and thus no

further margins. c. 765/400 kV ICT at Unnao. d. Loading of 400 kV Dadri-Muradnagar and Merrut-Muzaffarnagar:

Expediting, new 400 kV substations at Saharanpur, Bagpat, Hapur etc.

e. Transmission system associated with Anpara D, Bara TPS etc.

vi) Import/connectivity of J&K:

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a. Interconnection at 400/220 kV New Wanpoh and Samba substations in J&K.

vii) Rajasthan:

a. Transmission system associated with Kawai/Kalisindh/Chhabra TPS

viii)Import by Chandigarh: a. Main reliance on 220 kV Nalagarh- ManiMajara lines.

ix) Haryana:

a. 400/220 kV connectivity at Jind, Bhiwani, Manesar substations b. 220 kV lines within Haryana state control area

c) For General matters: • Healthiness of installed capacitor & new capacitor installation. • Healthiness of protection system and defence mechanisms.

Members may like to take stock of preparedness.

B.7 Assessment of Total Transfer Capability/Available Transfer Capability

(ATC/TTC) of state control areas (Agenda by NRLDC) The CERC regulation on congestion mandates computation of TTC/ATC of its state control area by respective SLDCs. In Northern Region, Punjab and UP SLDC are undertaking this task. UP SLDC is also uploading the TTC/ATC figures on its website.

In order to further operationalize it, one day workshop on ATC/TTC was organized at NRLDC on 27th Feb 2015. In the workshop, methodology of computation of TTC/ATC has been discussed. Sessions were also taken by experts from UP and Punjab SLDC who are undertaking this task. Updated ‘All India Base Case’ has also been shared with all the participants to further undertake the studies. However, participation in the workshop from the state of Uttarakhand, Himachal Pradesh, Jammu Kashmir & UT Chandigarh was nil.

Members may deliberate so as that all the SLDCs in the region develop requisite capabilities to compute ATC/TTC of its control area in accordance with regulatory provisions.

B.8 Ensuring telemetry of new element before charging

NRLDC has often expressed that the telemetry is not made available before charging of the new element and utilities invariably make requests to charge the element without telemetry. Providing telemetry is mandatory requirement in accordance with IEGC and Central Electricity Authority (Technical Standards for Connectivity to the Grid) Regulations, 2007.

The matter was discussed in the 4th meeting of TeST sub-committee held on 06.02.2015. The sub-committee has made following recommendations:

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a) The correct single line diagram (SLD) associated with communication details

shall be made available to NRLDC 15 days before the proposed date of charging.

b) Database should be prepared at SLDC/RLDC level and data validity test should be completed 3 days before charging the element.

c) NRLDC shall observe the reliability after that for issuance of the charging code.

d) No charging code shall be issued by NRLDC, if telemetry has not been made available.

Members may approve above recommendations of TeST sub-committee.

B.9 SPS for 765 kV Agra-Gwalior

SPS for the contingency of Agra-Gwalior line was approved in 17th TCC/18th NRPC meeting held on 27th /28th Nov., 2010. The scheme was reviewed after upgradation of line to 765 kV.

B.9.1 Idetification of radial feeder by RVPNL for inclusion in the scheme

As per the scheme, RRVPNL was to identify the radial feeders at their 220 kV Kota sub-station. The matter is being discussed in the OCC meetings for quite some time. Further the matter had also been brought to the notice to management of RRVPNL in December 2014. However, radial feeders for automatic load shedding on SPS operation have not been identified in Rajasthan.

In view of the ensuing summer it is utmost important that SPS for 765 kV Gwalior-Agra line is fully functional to maintain grid security.

Members may deliberate

B.9.2 Mock testing of SPS Mock testing of this SPS was carried out on 24th December, 2014 and certain deficiencies were observed. The concerned utilities were requested to rectify these deficiencies. The status of the same is as under:

State/ Utility

Site Status during mock testing carried out on 24.12.2015

Status As on 09.03.2015

Haryana 220 kV Samaypur Working Working 220 kV Narwana Tripping has been

bypassed due to instructions from SLDC-Haryana since July-2014

HVPNL informed that the tripping has again been enabled.

220 kV Panipat PTPS-Chandauli ckt hasn’t been wired for

Yet to be rectified.

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tripping. Tripping & counter increment was not observed for PTPS-Munak line.

Punjab 220 kV Gobindgarh Working Working 220 kV Laltokalan Counter didn’t increase

but actual tripping was reported by Lalto kalan.

POWERGRID informed that Counter is to be replaced.

220 kV Jamsher SPS installed, actual line tripping wasn’t observe. Problem in DTCP link.

Problem rectified

220 kV Mohali Working Working UP 220 kV Modipuram Working Working 220 kV Nara Fibre problem in

220kV Nara link. It is to be rectified

Problem rectified.

220 kV Mainpuri Working Working Rajasthan 220 kV Alwar 132kV Ramgarh is not

connected in Group-D. It is non-radial. 132kV Malakheda is connected in Group-D but it is also non-radial.

Rajasthan informed that these feeders are normally kept in radial mode only

220 kV Bhilwara Hamirgarh has been upgraded to 220 kV and now Rajasthan has to identify new feeders.

Rajasthan has yet to identify new feeders.

220 kV Kota Scheme not commissioned as RVPNL has not identified the radial feeders

Scheme not commissioned as RVPNL has not identified the radial feeders

220 kV Merta Although tripping has been bypassed but tripping occurred in real time. Rajasthan has to Check.

Rajasthan has to Check.

It may be seen from the above table that deficiencies at Panipat, Laltokalan and Bhilwara are yet to be rectified. Further, the scheme is yet to be implemented at Kota as RVPN has not identified radial feeders for load shedding.

In view of the above deficiencies the load relief would not be sufficient in the eventuality of operation of SPS and system safety and security is being compromised.


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B.10 Relief from SPS operations in Northern Region The issue of load relief obtained upon operation of System Protection Schemes (SPS) is being discussed regularly in Operation sub-committee Meetings. It has been discussed in the above meetings that relief obtained is only of the order of 20-30% of the planned relief. (The data in respect of December-2014, January-February 2015 is given at Annex-V). It has been well appreciated that the SPS schemes are for security of the system and at times are last efforts for secure operation of the grid. Therefore, greater reliability of load relief is required. In order to enhance the reliability of the SPS a scheme following is suggested:

a) While planning the schemes, minimum load on the feeder to be considered.

b) A nodal officer in each state for collating the analysis of the SPS operations and suggesting remedial measures.

c) For all new schemes,

• SPS signal recording in the Event Logger (EL) and Sequence of Event (SoE) recorder at all substations including intervening substations shall be implemented.

• SPS signal recoding in SCADA system of SLDC/RLDCs

d) Possibility and implementation of the requirement at point (c) above, in existing schemes shall also be explored.

Member may deliberate.

B.11 Deployment of adequate Manpower in LDCs The issue of inadequate manpower has been under discussion at NRPC forum for quite some time. In recent times, the issue was discussed in the 27th TCC and 30th NRPC meetings held on 27th and 28th February 2014. It was agreed that in view of the growing importance of the field, there is need to enhance manpower at SLDCs dealing with SCADA, telecommunication and telemetry. The issue was also deliberated in 29th TCC and 33rd NRPC meetings held on 10th and 11th November 2014. The issue was again deliberated in the 4th meeting of TeST sub-committee held on 6th March 2015 in the context of inadequate manpower for running and maintaining State Estimator applications. The issue also came up during the certification ceremony of System Operators held on 17th February 2015, wherein a difficulty in deputing the system operators for training due to lack of adequate manpower was flagged. Recognizing the Load Dispatch Centres (LDCs) as distinct and important functional area in the Electric Supply Industry (ESI) of country, the Govt. of India constituted a committee headed by Shri G.B. Pradhan, the then Additional Secretary to the Govt. of India, in February 2008, to look into the various issues relating to manpower, certification and incentives for the personnel employed on system operation at

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various levels and also for ring fencing the load dispatch centres to ensure their functional autonomy. The Pradhan committee, after wide consultations with stakeholders and other experts, identified load dispatching as ‘mission critical’ activity and gave its recommendation in August 2008. The Committee has recommended a strength of 60-70 executives in each Load Despatch Centre. The major functional areas identified by it are System Operation, Market Operation, System Logistics and Establishment services. The breakup of manpower under these functional areas (apart from LDC head) is as given below:

Function area No of Executives System Operation 22 Market Operation 22 System Logistics 12 Establishment Services 12

The suggested organisation chart and detailed strength as given in the Committee report is given at Annex-VI.

It has been observed that the manpower strength at present in different LDCs in Northern Region is much below the above recommended strength. The deficient manpower deployment is affecting the operations. With the advent of Open access, expectations for increased reliability of power supply, the work load at LDCs has further increased. This is likely to increase further in view of likely implementation of ancillary services as well as large scale integration of renewables in the system.

The details of manpower deployed in various LDCs were sought by NRPC Secretariat. Only Rajasthan, U.P., Haryana, Punjab, Delhi and Himachal Pradesh have submitted the details. The details are summarised in Annex-VII.

It may be seen that only Rajasthan SLDC has manpower in accordance with recommendations of the Pradhan Committee (60-70 executives).

Members may deliberate. B.12 Guidelines for planning, procurement and deployment of Emergency

Restoration System In the 33rd meeting of NRPC held on 11.11.2014, it was suggested that CEA should evolve guidelines regarding ERS. Later, Secretary (Power), GoI vide letter dated 05.12.2014 addressed to Chief Secretaries of all the states had requested to issue directions to transmission utilities / transmission licensees to procure adequate number of Emergency Restoration Systems. The guidelines formulated by CEA for planning, procurement and deployment of Emergency Restoration System were also enclosed with this letter. The same is enclosed as Annex-VIII.

Members may update about action taken in the matter.

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B.13 Integration of renewables in the System (Agenda by NRLDC) The Govt. of India has taken Green initiative to install and operationalize major renewable power generation capacity in the country. The renewable generation is environment friendly as well as sustainable in the long run and therefore is essential for future growth of the Electricity Supply Industry. However, world over, the Un-predictability and variability are termed as major challenge in the integration of the renewables. The technical requirements for the renewable generators are also being updated / reinforced through various regulations. The frequency and voltage regulations are also being mandated from renewable generators in various part of the world.

An extract of the provisions in present CEA grid connectivity regulations for renewable generators is enclosed at Annex-IX.

The above CEA’s regulation came in force on 15th October 2013 and therefore, all renewable (wind and inverter based) generators shall comply with these regulations. The older stations were also required to retrofit the capability within 6 months’ time as per the agreement with the local licensee.

The non-availability of Low Voltage Ride through (LVRT) capability in the wind generators in Rajasthan state control area was evident in the 24th June 2014 grid incident and same has been discussed in the OCC meetings as well as matter has been raised through separate letters.

In view of large scale upcoming renewable generation in the system, the requirements are to be strictly complied with and even better requirements based on international trends/developments are to be implemented.

Forecasting and scheduling is another important operational aspect of the renewable integration. The planning for the 20th March 2015, Solar eclipse in Germany wherein very high ramp rate of generation reduction and increase would be seen. This event is being debated world over and would give important lessons for large scale renewable integration. Requirement of improvement in scheduling/forecasting of two solar generators directly connected at regional level viz Unchahar and Dadri solar of NTPC has also been discussed during last OCC meeting.

Therefore, following requirements are essential for safe and secure operation of the system and large scale integration of renewables: i) Fault Ride Through (FRT) or Low Voltage Ride Through (LVRT). ii) Forecasting of Renewable generation. iii) Frequency Regulation. iv) Voltage Control & Reactive Power Compensation/Regulation. v) Bringing flexibility in the conventional generation resources to take care of

variability of renewable resources. Members may like to discuss and suggest ways for secure operation of the grid as well as large scale integration of renewables.

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B.14 Deficiencies observed / improvements suggested in Basic Protection Audit -

Compliance to directions of Hon’ble CERC in Petition no. 220/MP/2012 B.14.1 In the 27th NRPC meeting held on 30th November, 2012, it was decided that all

efforts should be made to squeeze the time for procurement of relays etc so as to rectify deficiencies observed in the Basic Protection Audit within a year i.e. before November, 2013.

The status of rectification of deficiencies (and expected completion) as submitted by the utilities is enclosed at Annex-X.

It is noted from the status that in case of some utilities the time frame for rectification of the deficiencies has extended much beyond original target and the work is now expected to complete by July, 2015.


B.14.2 In regard to rectification of deficiencies observed during Basic Protection Audit, Hon’ble CERC vide order dated 21.02.2014 in the petition no 220/MP/2012 had directed Member Secretary of Regional Power Committees to continue monitoring of rectification of deficiencies and submit report on quarterly basis. In compliance to above direction of Hon’ble Commission, NRPC Secretariat had submitted 1st status Report on 22.08.2014, 2nd status Report on 02.12.2014 and 3rd status Report ending December, 2014 on 18.02.2015 respectively.

B.15 Protection audit of intra-state system / balance system not covered in Basic

Protection Audit. In the 27th NRPC meeting held on 30th November, 2012, it was decided that States would initiate process of third party protection audit for their system and would complete it by August 2013. The status of the same is as under:

• The protection audit in case of RRVPNL, RRVUNL, BBMB, UPRVUNL & THDCIL (400 MW Koteshwar HEP) had been completed by CPRI. Reports of BBMB and RRVPNL have already been discussed in the Protection Sub-Committee whereas reports of RRVUNL, UPRVUNL and THDCIL are yet to be discussed.

• UJVNL had also shown inclination to award this work to CPRI. UJVNL may update the status.

• Protection Audit of PSTCL, PSPCL, UPPTCL and Rosa Power is being carried out by CPRI and report of the same is awaited.

• HVPNL,DTL, JPL, PTCUL, HPSEB Ltd., PDD J&K, HPGCL, NPCIL, NHPC, APCLP, Chandigarh had desired to carry out the TPPA for their system from the

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team constituted from the pool of protection expert. The latest status is enclosed as Annex-XI.

In the 33rd NRPC meeting held on 11.11.2014, it was decided that Third Party Protection Audit for all the states should be completed by June, 2015 and work of rectification of deficiencies should be completed by December, 2015.

Utilities, for which TPPA has been completed, have been requested to submit the time bound action plan for rectification of deficiencies. Only NPCIL, HPGCL, NHPC, HPSEB Ltd (for Jassore) and APCPL have submitted the action plan.

Members are requested to prepare the action plan so as to rectify the deficiencies observed during TPPA by December 2015 in accordance with decision of NRPC and submit the action plan to NRPC Secretariat.

B.16 Defense mechanism

B.16.1 Revised Under Frequency Relay based automatic load shedding scheme (ALSS)

Based on the decision of NRPC following settings were decided for four stage automatic load shedding scheme through UFRs for NEW grid, with a total target of 8720 MW for Northern Grid.

It may be noted that the scheme has been implemented in all states except:

(a) Chandigarh, where it has been implemented partially (implemented for 49.2 Hz and 49 Hz) and

(b) J&K, where it has not been implemented at all.

In the last NRPC meeting, PDD, J&K had indicated procurement target of UFRs as December, 2014. PDD, J&K may indicate current status.

TCC/ NRPC may advise UT Chandigarh and PDD, J&K to implement at the earliest UFR based automatic load shedding scheme in accordance with decision of NRPC.

B.16.2 Ensuring functioning of defense mechanism

In the 27th meeting held on 30th November, 2012, NRPC had decided that all STUs would ensure load relief as per target and settings of UFR and df/dt relays as agreed in NRPC. It was decided that mock exercise for healthiness of UFRs would be carried out by utilities themselves on quarterly basis and report would be submitted to NRPC Secretariat and NRLDC. This exercise would be done at the end of March, June, September and December months.

Further, in the 28th TCC/ 31st NRPC meetings held on 23rd and 24th July 2014, following decisions were taken:

i) OCC should finalize a procedure for testing and self-certification of UFR by

utilities.

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ii) SLDCs should upload the information about quarterly test report on their website.

iii) All utilities while submitting quarterly self-certification should test UFR with frequency generators for which they should have sufficient nos. of frequency generator kits.

All STUs except PDD, J&K have submitted self-certification about healthiness of UFR and df/dt relays for the quarter ending December, 2014 though some of the STUs like DTL, PSTCL, HVPNL, PTCUL and UT, Chandigarh have not submitted the self-certification in the prescribed format. The issues have been highlighted in every OCC meeting.

The procedure for testing and self-certification of UFR and df/dt relays was approved by NRPC in its 33rd meeting held on 11th November, 2014.

TCC/ NRPC may impress upon the members to submit the quarterly self-certification of UFRs and df/dt relays in the prescribed format

STUs may brief about implementation of the items at (ii) and (iii) above.

B.17 Reactive compensation Proposal for installation of bus reactors at 12 Nos 400 kV and 17Nos. 220 kV sub-stations was discussed in the 29th meeting of NRPC held on 13th September 2013.

After deliberations, NRPC had approved installation of reactors at 400 kV sub-stations of POWERGRID and RVPNL. As regards 220kV bus reactors, POWERGRID had stated that the requirement would be firmed up in consultation with the States in separate meetings.

It was agreed in the 33rd NRPC meeting held on 11th November, 2014, that all STUs will study and finalise the requirement of reactors at 220 kV level in consultation with POWERGID. It was also agreed that NRPC Secretariat would call meetings for individual states to facilitate discussions in this regard. In this regard, meeting with Punjab & Haryana was convened on 30th January, 2015 and another meeting with all other states was held on 03rd March, 2015. Further, RRVPNL intimated in the 108th OCC meeting that location-wise details of 15 nos. of reactors at 220 kV level have been forwarded to POWERGRID for examining the same.

In the meeting held on 30.01.2015 with Punjab and Haryana, it was inter-alia decided that POWERGRID would email details of likely network of these states as available with them to the respective participant from these states. These states would point out errors and omissions, if any in the network details within a period of 1 week. However, POWERGRID has informed that response of these states to the details emailed was not received till 03.03.2015. Following is the gist of discussions in the aforesaid meetings:

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a) POWERGRID would carry out the study for assessing reactor requirement at 220 kV level in intra-state system.

b) The requirement of reactors would be worked out considering expected system conditions in the year 2017-18 to account for time required for procurement and installation.

c) Since minimum loads remain almost static, the minimum loads observed during 2014-15 would be considered for study. Delhi, Haryana, Punjab and Rajasthan provided the minimum load data in the meeting. NRLDC was requested to review the same.

d) POWERGRID would submit by email the network data as available with them to the concerned state for validation.

e) The states would validate the network data and email the same to POWERGRID within 15 days. POWERGRID had already submitted the data of Haryana and Punjab but validation from the states was awaited.

f) Reactor Studies would be carried out by assuming that all capacitors are under switched off condition.

States of Uttrakhand, HP and J&K did not participate in the meeting and their status could not be ascertained.

Members may deliberate so as to expedite finalization of reactors at 220 kV level in the intra-state systems.

B.18 Constraints in intra-state network

In the 27th NRPC meeting held on 30th November, 2012, NRPC had decided that all SLDCs would identify bottlenecks, constraints and overloading in the State transmission network and advise STUs accordingly to enable proper transmission planning.

Based on information available with NRPC Secretariat, all SLDCs except that of J&K and Rajasthan have informed constraints observed in intra-state system to the STU.

In the 30th NRPC meeting held on 28th Feb., 2014, PDD, J&K had agreed to do so within 15 days but no information is received from PDD, J&K.

In the 33rd NRPC meeting held on 11th November, 2014, it was agreed that action taken by STUs would be discussed in the meeting to be convened by NRPC Secretariat for reactive compensation at 220 kV as mentioned in item B.1.4. In this regard, meeting with Punjab & Haryana was convened on 30th January, 2015 and another meeting with all other states was held on 03rd March, 2015. In these meetings, STUs of Punjab, Haryana, Delhi and Rajasthan briefed about actions being taken for removal of constraints intimated by SLDCs.

Members may deliberate so as to ensure early action on the bottlenecks identified by SLDCs.

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B.19 Implementation of RGMO/FGMO Following generating stations have not implemented RGMO/FGMO:

(i) JKSPDC: 3 units at Baglihar HEP (ii) UPRVUNL: Anpara TPS 3 x 210

Obra TPS 4 x 200 MW SLDC of J&K (PDD J&K) and U.P. SLDC may update the action taken to get RGMO/FGMO implemented at Baglihar HEP and at Anpara TPS & Obra TPS.

In 31st NRPC meeting held on 24th July, 2014 NTPC intimated that they have filed the petition with Hon’ble CERC for seeking exemption from RGMO for Badarpur TPS and Singrauli TPS.

NTPC may update the status.

B.20 Status of commissioning of new generating units The status of commissioning of new generating units in 2014-15, 2015-16 and 2016-17 as updated in the last OCC meeting is at Annex-XII.

This is for the information of Members.

B.21 Up-gradation of Black Start Facility during Grid Failure / Disturbance at NTPC-Auraiya with Black Start DG set (Agenda by NTPC)

NTPC-Auraiya is equipped with Emergency Gas Turbine (EGT) to provide black start facility to start Gas Turbines and supply power to grid in case of grid disturbance. The EGT is coupled with generator having capacity – 3710 KVA / 2968 KW at 6.6 KV.

In recent times, Station has encountered various problem related to EGT due to obsolescence and aged Hot Gas path Components, obsolete C&I controls, etc. As such, starting of EGT is unreliable. During grid disturbances in July 2012, EGT failed to provide black start service on both days i.e. 30th and 31st July on first attempt.

The reliability of black start facility for Auraiya Gas Power Station is of critical importance as the station is identified as an important Black Start facility after grid failure for restoring power to the North-Central Sub System of NR as per the “System Restoration Procedure for Northern Region” - critical Railway traction loads at Agra, Mathura & Phaphund are dependent on power generated at Auraiya Gas Plant.

For making EGT operationally reliable, the OEM has given a cost estimate of Rs.13.70 Crores. However, the Black Start requirement can also be met by installing a new compatible DG Set which costs about Rs.7.56 Crore. All other NTPC Gas Stations (Anta, Dadri-Gas & Faridabad) are already equipped with Black Start DG set & are proven for their reliable operation.

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In view of the lower cost of a new DG Set vis-à-vis up-gradation of EGT, NTPC has proposed for replacement of EGT with a new compatible DG set for ensuring enhanced reliability of the system during grid restoration process.

The above proposal of NTPC for replacement of EGT with a new compatible DG set at Auraiya at an estimated cost of about Rs.7.56 Crore was discussed in the 108th OCC meeting held on 19th& 20th February, 2015. OCC had agreed with the proposal on technical considerations and decided to recommend the proposal for approval of TCC/ NRPC.

Members may deliberate and approve.

B.22 Follow up of Major Decisions of NRPC.

Sl.No Name of the Project

Approved in

status furnished during 33rd NRPC meeting

Latest status /Issues

1 Automatic Meter Reading (AMR) for SEMs

13th NRPC meeting held on 24th June 2009.

NRLDC reported that AMR data was being received only from 45 locations. POWERGRID informed that Commissioning of AMR for 220 locations shall be completed by end of December, 2014. Work on additional 29 locations shall be taken up thereafter.

SJVN Ltd has stated that AMR required for NJHPS & Rampur HPS stations have not been installed by CTU and same is required to be installed during present lean period of generation i.e. before March 2015. In the 28th commercial sub-committee meeting, it was informed by NRLDC that the same shall be completed by 15.03.2015. SJVN Ltd has requested NRLDC to expedite the same.

POWERGRID may update the latest status.

2 Implementation of underlying network at Wanpoh and Samba.

i) PDD, J&K will send proposal to POWERGRID for underlying network on bilateral tariff basis.

i) PDD, J&K to update the status.

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Approved in



ii) POWERGRID informed that proposal for exemption of tariff based bidding for LILO of Samba-Hiranagar line at Samba 400 kV was agreed by Empowered Committee in its meeting on 30.09.14. Notification of MoP for exemption was awaited.

(ii) POWERGRID to update the status.

3 Expansion of Unified Load Dispatch System Centre scheme of NR (Phase-II).

18th NRPC meeting held on 27th November, 2010.

Parallel operation of new SCADA with existing one had started and old SCADA system would be discontinued by December, 2014. All SLDCs to intimate the problems being faced with new SCADA to NRPC sectt. for inclusion in the Agenda of TeST sub-committee meeting to be held on 21.11.2014.

Now, the system operation is being carried out with new SCADA system under ULDC Phase-II. Major teething problems have been resolved as clear from discussions in the 4th meeting of TeST sub-Committee. Remaining issues will be resolved progressively. For information of members.

4 Provision of Bus Reactors in Northern Region to Control Over Voltages

Approved in 15th NRPC meeting on 24th December, 2009

Out of 17 no reactors at 15 locations, 10 no reactors had been commissioned at 9 locations. Status of remaining 06 locations was as under;-

NathpaJhakri (1x80 MVAr): Reactor received at site. Since, single quotation by M/s BHEL for GIS Bays was costly, open tendering will now be done. Time line would be informed later.

SJVN Ltd may update the status.

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Approved in



Chamera-I (1x125 MVAr): LoA of reactor by Jan., 2015 with commissioning in 12-15 months thereafter. NIT for GIS yet to be floated.

NHPC may update the status.

Parbati-II (1x125 MVAr) and Parbati-III (1x80 MVAr): There is no space at Parbati-III and as such reactors will be installed at Parbati- II. Reactors at Parbati-II will be commissioned along with the commissioning of the project in 2017-18.

NHPC may update the status.

Rihand (1x 80 MVAr): Commissioning expected by December, 2014.

NTPC may update the status.

Dehar (2X 63 MVAR) Included in item 10(below) of this table.

Included in item 6(below) of this table.

5 Proposal for implementation of state of art PABX system

27th NRPC meeting held on 30th Nov, 2012

PABX system has been installed at NRLDC and would be installed at all SLDCs progressively by March, 2015.


6

2X63 MVAR Bus reactor and replacement of 250 MVA Trf. with 315 MVA Trf. at Dehar Power House by POWERGRID.

Approved in 30th Standing Committee of Power System Planning of NR held on 19.11.2011

LoA for Transformer & Reactor was placed in Feb’14 with completion schedule of Aug’15.GIS has been retendered and completion schedule for entire works is December, 2015.


7 Unified Real Time Dynamic State

Approved in 27th NRPC

Survey of 106 sites out of 108 sites completed.


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Approved in



Measurement (URTDSM) Scheme.

meeting held on 13th July, 2012 &30th November, 2012

20 nos. PMUs expected in Jan., 2015.

8 LILO of 400kV Dehar-Panipat S/C and 400 kV Dehar-Bhiwani S/C by Power Grid.

Approved as part of NRSS-XXVII in the 29th Standing Committee NR held on 29.12.2010.

LILO of Dehar-Panipat by Dec., 2014. RoW issue for Dehar-Bhiwani, was to be discussed in a high level meeting with Punjab Govt scheduled on 18.11.2014. NRPC Secretariat has requested CEA to resolve the issue regarding ownership raised by BBMB.

POWERGRID may update the status regarding completion of work.

9 Power Evacuation from Dulhasti Power Station, Kishtwar (J&K) – Construction of 2nd 400 kV line

28th Standing Committee

The matter is pending with Forest Department, J&K at DFO level. No meeting on the matter could be held at State level due to recent flood in J&K. Completion schedule:- 04 months after the clearance from Forest Department of Govt. of J&K.


10 Transmission system associated with RAPP-7&8. • Kota – Jaipur (South) 400 kV D/c (part of RAPP – Jaipur (South) 400 kV D/c line with one ckt LILOed at Kota) • 2 nos. of 400 kV line bays at Jaipur (South) • 1 no. 400 kV

Commissioning schedule of Generation project is Nov., 2017. Completion of Transmission project will match with the commissioning of generation project.


23



Approved in



line bay at Kota 11 Transmission

system associated with Kishenganga HEP. o Kishenganga – Amargarh 220 kV D/c o Kishenganga – Wagoora 220 kV D/c

33rd Standing Committee Meeting held on 23/12/2013

Commissioning schedule of Generation project is December, 2016 Transmission project will match with the commissioning of generation on best effort basis.


C O M M E R C I A L I S S U E S

C.1 Scheduling of Un Requisitioned Surplus (URS) Power from Indira Gandhi

STPS, Jhajjar The issue of scheduling of URS power from Indira Gandhi STPS Jhajjar (owned by APCPL) to defaulting states was discussed in 29th TCC and 33rd NRPC meetings. It was decided that a group would be constituted, which would study the case and submit report to NRPC.

Accordingly, a group comprising of following members was constituted by Member Secretary, NRPC vide letter No. NRPC/ Comml/ 209/ RPC (33rd)/2014 dated 16th January, 2015:

1. Sh. Ajay Talagaonkar, Superintending Engineer, NRPC 2. Sh. H.K. Chawla, DGM, NRLDC 3. Sh. Anil Nautiyal, AGM, APCPL

The group has submitted its report on 12.02.2015, which is enclosed at Annex-XIII. The recommendations are as follows :

a) NRLDC will continue the present practice of URS Scheduling i.e to Schedule the URS Power based upon the requisitions received from beneficiaries. However, as a special case, request from APCPL to NRLDC regarding URS power scheduling would be taken care of while scheduling URS power till 31st March, 2015.

b) Further action beyond 31st March, 2015 shall be based on uniform procedure finalized after deliberations in Commercial sub-committee meeting and TCC/NRPC meetings.

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This issue was discussed in the 28th Commercial Sub Committee meeting held on 16.02.2015.

Representative of NRLDC stated that the software for web based scheduling is under development which would be used by all the RLDCs. Therefore, scheduling procedure shall be same for all the generators across the regions. Further, since scheduling has the commercial implications RLDCs would not like to schedule URS without express consent of generators.

Representative of NTPC stated that the process of obtaining consent of generators for scheduling of URS power may lead to delay and ultimately lead to loss of opportunity for utilization of URS power. In view of this he proposed that the existing procedure followed by NRLDC may be continued.

NRLDC stated that ERLDC is also following the practice of obtaining consent of generators for scheduling of URS power.

SE, NRPC opined that Hon’ble Commission’s order dated 11.01.2010 in the petition No 134/2009 clearly implies that onus of scheduling URS power rests on generators.

After deliberations, it was decided that the constituents would submit considered opinion of their organization by 28.02.2015.

However, NRPC Secretariat has not yet received opinion from any of the constituent.

Members may deliberate so as to evolve a common methodology to be adopted for URS scheduling of all generators.

C.2 Default in payment of outstanding dues of NHPC by beneficiaries (Agenda by

NHPC)

The details of outstanding dues for more than 60 days as on 19.02.2015 in respect of defaulting beneficiaries of NHPC are as given below:

Amount ₹ in Crs

Sl. No.

Beneficiary Principal Outstanding

Dues

Surcharge Outstanding dues including surcharge

1. PDD, J&K 1269.40 308.02 1577.42 2. HPSEB Ltd 13.59 1.01 14.60 3. PSPCL 13.36 2.80 16.16 4. BRPL 78.88 13.80 92.68 5. BYPL 123.69 34.04 157.73 6. Rajasthan Discoms (i) AVVNL 57.13 6.85 63.98 (ii) JdVVNL 39.99 8.25 48.24 (iii) JVVNL - 12.76 12.76

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Total 97.12 27.86 124.98

Above beneficiaries are defaulting in making payment in spite of vigorous follow up by NHPC and raising of the issue in various RPC meetings. It is pertinent to mention that PDD,J&K has not released any payment since Oct’2014. Further, BRPL and BYPL are not even adhering to the orders of Hon’ble Supreme Court for timely payment of current dues. Rajasthan discoms except JVVNL are not releasing adequate payment against their outstanding dues.

The above beneficiaries may kindly be impressed upon to liquidate the outstanding dues on priority. In case of continuation of such defaults, NHPC may go for regulation of power as per CERC Regulations.

C.3 Opening of Letter of Credit (LC) in favour of NHPC (Agenda by NHPC) BYPL: LC opened by BYPL had expired on 31.03.14 and further they did not open the LC of requisite amount i.e. ₹ 14.49 Crs in favour of NHPC till date even after repeated requests.

The beneficiary may kindly be impressed upon to open Confirmed, Irrevocable & Revolving Letter of Credit for the requisite amount in favour of NHPC Ltd.

C.4 Signing of Bulk Power Supply Agreement (Agenda by NHPC)

The beneficiaries i.e. Discoms of Delhi (BYPL, BRPL & TPDDL), are not renewing the Bulk Power Supply Agreement (BPSA) for the power stations, from which they are drawing power, despite our repeated requests.

These beneficiaries may kindly be impressed upon to renew the BPSA with NHPC at the earliest.

C.5 Signing of Reconciliation statement as per BPSA of NHPC (Agenda by NHPC):

(i) PDD J&K:No surcharge is being paid by PDD, J&K from the payment released

by them since April’13 for the surcharge bill dated 07.08.2012.

(ii) Rajasthan Discoms ( JVVNL, JdVVNL & AVVNL): Rajasthan discoms have not accepted the surcharge adjusted by NHPC. They have requested for waiver of surcharge up to 30.11.2013 which cannot be accepted by NHPC as surcharge is determined as per prevalent rules of CERC.

These beneficiaries are requested to accept the surcharge adjusted by NHPC and sign the reconciliation in all respect.

C.6 Delay in release of payment of SJVN bills by the beneficiaries of Nathpa Jhakri Hydro Power Station (Agenda by SJVN)

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a) As on 21.02.2015, an amount of Rs. 1292.91 Crore is outstanding for a period more than sixty (60) days from some of the beneficiaries of NJHPS. The beneficiaries who have not cleared their outstanding dues are Govt. of HP, PDD J&K, UPPCL, BRPL, BYPL, Rajasthan Discoms , HPSEB and PSPCL as per detail given below:

Sr. No Name of Beneficiary Overdue Outstanding including LPS in Rs Crore

1 GOHP 485.76 2 J&K 306.08 3. UPPCL 217.60 4. BRPL 99.30 5. BYPL 80.39 6. Ajmer VVNL 46.45 7 Jodhpur VVNL Rajasthan Discoms 27.81 8 Jaipur VVNL 11.19 9 HPSEB 17.81 10. PSPCL 0.52

Total 1292.91

b) GOHP and HPSEB: Since last meeting of TCC/NRPC held in Nov 2014, HPSEB has released only Rs 30.14 crore against allocated power. Further, since Dec 13 Govt of HP has assigned their equity power to HPSEB and since Nov 14, an amount of Rs. 66.12 crore only was received against equity power and outstanding dues has increased to Rs 17.81 Crore against HPSEB and Rs 485.76 Crore against GOHP.

c) PDD J & K: An amount of Rs 306.08 crore is overdue from J & K. In this FY i.e. 2014-15 J & K has released only Rs 5.00 crore during the month of April 14 and thereafter, SJVN has not received payments in-spite of our repeated follow-up & periodical visits to higher official of J & K Govt.

d) BRPL : Since last meeting of TCC/NRPC held in Nov 2014, BRPL has released only Rs 2.00 crore during January 2015 and outstanding dues has increased to Rs 99.30 Crore.

e) BYPL: Due to continuous default by BYPL, their power is regulated since September 2013 and outstanding dues has increased to Rs 80.39 Crore.

f) Rajasthan Discoms : In-spite of assurance of Rajasthan Discoms during the last NRPC/TCC meeting to liquidate their dues of more than 60 days, their current status is as under:

i) Ajmer Vidyut Vitaran Nigam Ltd : Since last meeting Ajmer has released only Rs 5.00 Crore against dues and their outstanding had reached Rs 46.45 Crore as on 21/02/2015.

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ii) Jodhpur Vidyut Vitaran Nigam Ltd: Since last meeting Jodhpur had released only Rs 19.00 Crore against outstanding and their outstanding had reached Rs 27.81 Crore as on 21/02/2015.

iii) Jaipur Vidyut Vitaran Nigam Ltd : As on 21/02/2015, Rs 11.20 Crore is outstanding.

g) DTL: An amount of Rs 8.50 crore is overdue from DTL inclusive of LPS for the bills raised in 2009-2010. A meeting was held with the management of DTL on 20/11/2014 to resolve the issue and DTL officials visited SJVN office during Dec 14 to further deliberate the matter. The matter is still under discussions.

h) PSPCL: An amount of Rs 52 Lacs is outstanding from PSPCL. This amount is due on short deductions made by them from the bills and on account of LPS levied by the SJVN. The SJVN is open for meeting with PSPCL for resolving the issue.

It is requested that the NRPC may intervene in liquidation of outstanding dues from the above defaulting entities.

C.7 Non Opening of Letter of Credit by certain beneficiaries for power supplied

from NJHPS (Agenda by SJVN) As per provisions of CERC regulations and terms and conditions of power purchase agreement, beneficiaries are obligatory required to submit the Letter of Credit (LC) before start of the relevant financial year, but the following beneficiaries are yet to submit their LC.

a) Power Development Deptt. of J&K:

Power Development Department of J&K has not yet opened Letter of Credit since May 2011 whereas as per the Power Purchase Agreement they have to submit a confirmed, revolving, irrevocable Letter of Credit in favour of SJVN for an amount equivalent to 105% of their average monthly billing of preceding 12 months with appropriate bank as mutually acceptable to parties. The LC shall be kept valid at all the time during the validity of the Power Purchase Agreement. As such Power Development Department of J&K may be impressed upon to submit valid Letter of Credit to SJVN as per terms of PPA.

b) BYPL and BRPL:

Further, BRPL and BYPL is required to submit a confirmed, revolving, irrevocable Letter of Credit in favour of SJVN for an amount equivalent to 105% of their average monthly billing of preceding 12 months with appropriate bank as mutually acceptable to parties. The LC shall be kept valid at all the time during the validity of the Power Purchase Agreement.

Both the beneficiaries are yet to submit Letter of Credit for FY 2014-15. As such the same needs to be opened on priority basis.

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c) Govt. of HP:

Since Dec 13, GOHP has assigned their power to HPSEB. Despite the instruction from Principal Secretary Power, Government of Himachal Pradesh, HPSEB is yet to open the Letter of Credit against the power assigned to them by GoHP.

C.8 Opening of Letter of Credit for FY 2015-16 (Agenda by SJVN)

Letters were issued to the beneficiaries for opening /renewing Letter of credit for 2015-16 and all the beneficiaries may be impressed upon to open or renew the existing LC before the expiry of current LC.

C.9 Signing of PPA for RHEP of SJVN Limited (Agenda by SJVN)

Ministry of Power has allocated RHEP power to UT- Chandigarh from unallocated quota. UT-Chandigarh is yet to sign the PPA with SJVN for RHPS power. However, the PPA duly signed by SJVN has already been forwarded to their office on 16.12.2015 for signing the same, which is pending inspite of reminders from SJVN

UT – Chandigarh may please be impressed upon to sign the PPA at the earliest.

C.10 Inordinate Delay in release of THDCIL’s payments by its beneficiaries

(Agenda by THDCIL) THDCIL India Limited (THDCIL) has been supplying energy from its presently operating Tehri HPP and Koteshwar HEP generating stations to all the beneficiaries of Northern Region. Despite vigorous expediting, some of the beneficiaries have been inordinately delaying payments to THDCIL. Due to non-payment of outstanding amount, there has been financial hardship in the THDCIL to the extent of forcing it to avail overdraft and borrowings to meet day to day working capital needs and funding ongoing capital expenditure of different projects under construction. The following beneficiaries may release the payments immediately so that THDCIL is not forced to default in servicing its lenders/ creditors including its employees:

a) Delhi Discoms (BRPL & BYPL) :

BYPL has not released the payment of various bills pertaining to supplies since December, 2012 onwards. At present a total amount of ₹ 155.98 Cr. is outstanding to be paid by BYPL, out of which ₹ 142.80 Cr. is due for more than 60 days.

BRPL has not cleared payments of various bills pertaining to the supplies made for the period November, 2013 onwards. At present a total amount of ₹ 121.97 Cr. is outstanding to be paid by BRPL, out of which ₹ 102.78 Cr. is due for more than 60 days.

BYPL and BRPL are not even adhering to the orders of Hon’ble Supreme Court for timely payment of current bills. They may take necessary action immediately to release the outstanding amount of ₹ 142.80 Cr. and ₹ 102.78 Cr. respectively,

29


which is due for more than 60 days, without any further delay. In case they are not able to release these payments immediately, then must inform a time-bound payment plan to liquidate these dues. Furthermore, BYPL and BRPL have to make payments against LPSC bills forthwith.

b) UPPCL, Uttar Pradesh :

UPPCL has not released the payment of various bills pertaining to supplies since September 2014 onwards. At present a total amount of ₹ 355.86 Cr. is outstanding to be paid by UPPCL, out of which ₹ 194.58 Cr. is due for more than 60 days. UPPCL is the largest stakeholder as approx. 46% billing is done on them. The amount outstanding on UPPCL is huge & critical for THDCIL. The delay in release of payment by UPPCL creates cash crunch in THDCIL.

UPPCL may release the outstanding amount of ₹ 194.58 Cr. without any further delay which is due for more than 60 days. After release of this amount, UPPCL may kindly arrange to release the monthly payments within the due date in future so that working capital requirements of THDCIL are met.

c) PDD, J&K :

PDD, J&K has not released payment against various bills related to sale of energy pertaining to the supplies since March 2014. On account of excessive delay, huge amount has accumulated on PDD,J&K. THDCIL being a small organisation, faces difficulties in arranging working capital in case of defaults in making payment. At present a total amount of ₹ 125.53 Cr. is outstanding to be paid by PDD, J&K, out of which ₹ 96.84 Cr. is due for more than 60 days which is huge and critical amount for THDCIL.

PDD, J&K may take necessary action immediately to release the outstanding amount of ₹ 96.84 Cr. which is due for more than 60 days and inform a time bound payment plan to liquidate the old outstanding dues.

PDD, J&K did not open LC till date even after repeated requests. PDD, J&K may kindly be impressed upon for opening of LC on priority.

d) Other Beneficiaries

Beneficiaries/ Discoms

Payment due pertaining to the supplies from the

month

Amount Due

( ₹ in Cr.)

Amount Due for more than 60

days ( ₹ in Cr.)

HPSEBL, Himachal Pradesh

Jan’ 2015 5.57 2.71

JVVNL, Rajasthan Nov’ 2014 16.87 4.13 AJVVNL, Rajasthan Aug’ 2014 23.02 13.75 JdVVNL, Rajasthan Sep’ 2014 22.63 12.17

30


HPSEBL, Himachal Pradesh and Rajasthan Discoms may take necessary action immediately to release the above outstanding amounts without any further delay.

The above beneficiaries have not released any payment against the Late Payment Surcharge (LPSC) bills till date even after repeated requests. HPSEB & Rajasthan Discoms have to make payments against LPSC bills forthwith. As such, they may also take immediate action to release the payment against LPSC bills.

C.11 Outstanding dues more than 60 days of POWERGRID (Agenda by

POWERGRID)

Outstanding dues for more than 60 days are as under:

Name of Beneficiaries POC Billing PDD-J&K Rs. 262.58 Cr. BRPL Rs. 18.90 Cr. AVVN Rs. 27.45 Cr. JDVVN Rs. 22.46 Cr. JVVN Rs. 3.86 Cr.

Utilities are requested to liquidate the outstanding amount at the earliest.

C.12 OPENING OF LETTER OF CREDIT (Agenda by POWERGRID) C.12.1 Opening of LC by PDD-J&K

PDD-J&K has not opened irrevocable monthly revolving Letter of Credits, which is mandatory as per CERC Regulations despite repeated reminders/notices & personal meetings. The issue is also being raised regularly in all the Commercial Committee meetings. However, no action has been taken by PDD-J&K .

C.12.2 Enhancement of LC amount by BRPL

LC submitted by BRPL are of Rs. 21.43 Cr. (For POC bills) ,valid upto 31.03.2015 BRPL has to open irrevocable monthly revolving Letter of Credits for Rs. 64.19 cr. (210 %) towards POC and Rs. 2.65 Cr. (210 %) towards Non POC, incorporating our standard ‘Special Conditions to Letter of Credit’ already sent. No action so far even after repeated reminders /notices & personal meetings.

C.12.3 Enhancement of LC amount by BYPL

BYPL has submitted LC for Rs. 17 Cr. (POC bills) instead of Rs. 43.12 Cr (210%) towards POC having validity upto 31.03.2015. BYPL has opened Revocable standby LC with additional condition stating validity of LC is 31.03.2015 or date of invocation whichever is earlier, which is not as per POWERGRID terms & conditions of LC. BYPL has to enhance the existing LC incorporating our standard

31


‘Special Conditions to Letter of Credit’ already sent. No action so far even after repeated reminders /notices & personal meetings.

C.12.4 Enhancement of LC amount by JDVVNL

JDVVNL has submitted LC for Rs. 15.60 Cr. instead of Rs. 20.02 Cr towards POC bills, valid upto 31.03.2015. JDVVNL has to extend and enhance irrevocable monthly revolving Letter of Credits. No action so far even after repeated reminders /notices & personal meetings.

C.12.5 Enhancement of LC amount by AVVNL

AVVNL has submitted LC for Rs. 14.20 Cr. instead of Rs. 17.77 Cr towards POC bills, valid upto 31.03.2015. AVVNL has to extend and enhance irrevocable monthly revolving Letter of Credits. No action so far even after repeated reminders /notices & personal meetings.

C.12.6 Enhancement of LC amount by JVVNL

JVVNL has submitted LC for Rs. 16 Cr. instead of Rs. 24.84 Cr towards POC bills, valid upto 28.02.2015. JVVNL has to extend and enhance irrevocable monthly revolving Letter of Credits. No action so far by JVVNL even after repeated reminders / notices & personal meetings.

C.12.7 Revalidation of LC by PSPCL

PSPCL to incorporate our standard ‘Special Conditions to Letter of Credit’. No action so far by PSPCL even after repeated reminders /notices & personal meetings.

C.12.8 Incorporation of Special Conditions to LC by UPCL

UPCL has to incorporate already sent standard ‘Special Conditions to LC’ in Letter of Credits. No action so far even after repeated reminders /notices & personal meetings. UPCL may incorporate, Special conditions, while establishing new LC from 01.04.2015.

C.12.9 Revalidation /Enhancement of LC amount by UPPCL

UPPCL has submitted LCs amounting to (i) Rs. 5 Cr revolving twice in a month (i.e. Rs. 10 Cr.) valid upto 30.05.2015 issued by ICICI Bank; (ii) Rs. 10.0 Cr. revolving 5 times in a month (i.e. Rs. 50.0 Cr. issued by PNB lapsed on 30.06.2015 and (iii) Rs. 8.5 Cr. revolving 5 times in a month (i.e. Rs. 42.5 Cr. issued by PNB, lapsed on 30.06.2015 ) totaling to Rs. 102.5 Cr. against requisite LCs of Rs. 124.76 Crores towards POC bills respectively. Therefore, LCs needs to be extended and enhanced for the said amount having validity for one year from the date of issue incorporating our standard ‘Special Conditions to Letter of Credit’ already sent.

C.13 LC status against Deviation Charges delayed payment (Agenda by NRLDC)

32


Based on the information received from NRLDC, latest status of opening of LC against Deviation Charges delayed payment is as follows:

S. No. Name of NR Pool members

LC Amount (Rs. in Cr.) Status

No of defaults in Deviation Payment in 2014-15

1 UPPCL,UP 58.60 Not opened 39

2 UPCL, Uttarakhand

6.27 Not opened 25

3 HPSEB, Himachal Pradesh

9.96 Not opened 38

4 PDD,J&K 14.82 Not opened 41 5 EPPL 0.59 Not opened 35 6 LANCO, Budhil 1.20 Not opened 27 7 Punjab 19.80 Not opened 4 8 DTL 4.97 Not opened 2 9 JPVL 4.51 Not opened 9

NRLDC vide letter dt 20.2.2015 has again requested entities who defaulted in payments to open the LC against Deviation delay Payment as per CERC Regulations. Utilities may please update the status of LC Openings.

C.14 Payment of NRLDC fee and charges (Agenda by NRLDC)

NRLDC is raising the bills towards NRLDC fee and charges from Oct., 2010 as per the Order dtd. 11th March, 2011 passed by CERC in petition NO. 91/2010 for the control period 2009 – 14 in accordance with CERC (Fee and charges of Regional Load Despatch Centre and other related matters) Regulations, 2009. The status of NRLDC Fee & Charges is as below:-

S No Name of User Amount

Outstanding in Rs Lakhs

Remarks

1 Malana,-II HEP 18.11 May-14 to Nov-14 Bills

2 Delhi Control Area 19.10 Part payment from Apr-14 to Nov-14

Bill (Delhi Seller Portion)

3 J&K Control Area 114.29 Apr-14 to Nov-14 Bills

4 Rajasthan 18.29 Oct-14 and Nov-14 Part Payment.

5 Himachal Pradesh 11.68 Oct-14 bill.

33


6 Lanco Budhil 11.80 July-14 to Nov14 bills

Above users are requested to release the outstanding payments.

C.15 TDS Certificates against STOA and RLDC Fee & Charges (Agenda by NRLDC)

NRLDC is in the process of reconciliation of TDS deducted by the applicants/users on STOA/RLDC Fee & Charges payments. Details of TDS deducted /certificates are not being furnished to the NRLDC on a regular basis by some of applicants/users. It is requested that TDS being deducted may be deposited with the Tax authorities by the 7th of every month for the previous month & details with challan numbers be submitted to NRLDC by the 10th of every month for the previous month. TDS Certificates may be submitted on a quarterly basis.

Further TDS Certificates against RLDC Fee & Charges for the period Oct 10-March 14 may be mailed to avoid any delay in making refund to the respective users after the completion of truing up exercise by NRLDC.

Non submission of details of TDS/proof of depositing TDS with the Tax authorities is similar to default in payment. Such default will be considered by NRLDC in terms of Regulation 19(1) of the CERC Open Access in Inter-State Transmission Regulations 2008 ie “19. (1) In case of default in payment of the application fee or the charges specified under these regulations, the nodal agency may, in its discretion, decide not to schedule the transaction, or to cancel the scheduling of already scheduled transaction or not to entertain any application of such persons in future until such time the default is cured.”

It is requested that TDS information / certificates may be submitted to NRLDC regularly.

C.16 Reimbursement of SCADA/EMS AMC charges (Agenda by NRLDC) The AMC contract awarded by NRLDC for the SCADA/EMS system installed under ULDC scheme in Northern Region expired on 30.09.2014. As per the MOU executed with the entities, the payments were to be made in advance by Constituents based on the bill raised by NRLDC. As on date followings payments are yet to be received by NRLDC:

Figures in Rs. OCT07-SEP10 OCT10-SEP12 OCT12-SEP14 TOTAL DUE REMARKS

BBMB

PORTION

BBMB PORTIO

N BBMB

PORTION

UPPCL 0 0 0 0 0 0 0

PSTCL 0 0 0 0 64 891982 892043 JK -27921 0 87823 0 12397219 0 12457121

34


HPSEB 0 0 0 0 0 123790 123790

HVPNL 0 0 0 0 66759 0 66755 S.T. Deducted

DTL 0 0 -6 0 0 0 0

PTCUL 1428317 0 1994198 0 0 0 3422516

RVPNL 3779803 1326744 6155357 694623 4277026 4277026 20510579 UT-CHD 862157 862157 BBMB 1326744 694621 5292796 7314161

TOTAL 5180194 2653487 9099526 1389241 16741071 10585593 45649112 Since the contract period has already expired all the pending payments needs to be released/ reconciled by the Constituents at the earliest to close the contract.

D.1 Status of UI charges:

As per the information received from NRLDC, the status of payment of UI charges payable/Receivable by the utilities as on 28.02.2015 is as given below:

(Amount in Rs. Lakh)

Principal UI

Charges Interest on UI

charges Principal +

Interest

S.No Utility Name Net UI

Payable(+) or Receivable(-)

Net UI Interest Payable(+) or Receivable(-)

Net Amount Payable(+) or Receivable(-)

1 2 3=1+2 1. CHANDIGARH 0 0.14386 0.14386 2. JAMMU & KASHMIR 4876.89253 860.80935 5737.70188 3. NEPAL 0.00334 0.00012 0.00346 4. UTTAR PRADESH 121186.2291 0 121186.2291 5. UTTARAKHAND 0 0.03544 0.03544 6. NHPC 0 -3.29799 -3.29799 7. THDC 0 -0.02031 -0.02031 8. EPPL 36.12205 2.63738 38.75943 9. JPVL 0.23972 0 0.23972

10. LANCO 0.11288 0.00416 0.11704 11. WR-NR 0 1.14174 1.14174 12. Pool Balance -126099.6097 -861.45375 -126961.0634

# i) These figures are based on UI regulations of CERC. However, the differential amount of Rs. 16039.76272 Lakh is there due to different UI ceiling rate as per CERC Regulation on UI Charges and High Court of Allahabd, Lucknow bench order dated 2.5.2008 and CERC order dated

D. ITEMS FOR NRPC ONLY

35


29.5.2008 for implementation of High Court order which is subject to review based on the conclusion of the proceeding in the matter presently pending in High Court. ii) The additional UI charges of UP for the FY 2009-10 and up to week 5 of FY 2010-11 are Rs.21085.71003 Lakh as per CERC Regulation on UI Charges which UPPCL was not required to pay in persuance of High Court of Allahabd, Lucknow bench order dated 12.11.2009 and CERC order dated 03.12.2010. iii) Accordingly the outstanding UI charges of UP is only Rs. 84060.75637 Lakh (Incuding interest).

D.1.1 UI charges outstanding against UP

Uttar Pradesh Power Corporation Ltd is failing in liquidation of outstanding UI payments. Hon'ble commission vide its order dt 28.01.14 in petition no 143/MP/2013 has directed UPPCL to liquidate Rs 600 crore by 31.03.2014 and the and the balance outstanding amount including current amount, if any, to be liquidated in equal monthly installments by 31.7.2014. Such payments are to be made before the last day of the month. NRLDC is to apprise the Commission about the UI payment status of UPPCL in the first week of every month starting from March 2014.

Last payment released by UPPCL against UI is only Rs. 185 Cr. in the month of Jan’2015(Rs. 28.27 Cr. against UI Principal and Rs. 156.73Cr. against UI delay payment Interest). As on 28th Feb’15 the total UI outstanding against UPPCL is Rs. 840.61 Cr. excluding the UI dues of Rs 371.25 Cr. covered under the orders of Hon'ble High Court of UP and UI Delay payment Interest is nil.

UPPCL is requested to intimate liquidation plan & release outstanding UI payments at the earliest.

D.1.2 UI charges outstanding against J&K

As on 28.02.2015, PDD J&K is to pay net UI charges (including interest) of Rs. 5737.70188 Lakh.

PDD J&K is requested to intimate liquidation plan & release outstanding UI payments at the earliest.

D.2 Status Of Deviation Settlement Charges Deviation Pool Account Fund of NR is being maintained & operated by NRLDC in accordance with the CERC Regulations. As per Regulations 10 (1) of “Deviation Charges Related matter” the payment of charges for Deviation shall have a high priority and the concerned constituents shall pay the indicated amounts within 10 days of issue of statement of Charges for Deviation including Additional Charges for Deviation by the Secretariat of the respective Regional Power Committee in too the “Regional Deviation Pool Account Fund” of the concern region.

As per the information received from NRLDC, the status of payment of Deviation charges payable/Receivable by the utilities as on 28.02.2015 is as given below:

36


(Amount in Rs. Lakh)

Principal DS

Charges Interest on DS

charges Principal +

Interest

S.No Utility Name Net DSC

Payable(+) or Receivable(-)

Net DSC Interest Payable(+) or Receivable(-)

Net Amount Payable(+) or Receivable(-)

1 2 3=1+2 1 CHANDIGARH 0.00010 0.00000 0.00010 2 DELHI 0.00000 6.35206 6.35206 3 HARYANA -114.30893 -0.11103 -114.41996 4 HIMACHAL PRADESH 532.16870 90.43266 622.60136 5 JAMMU & KASHMIR 17784.23785 383.70861 18167.94646 6 NEPAL 0.00000 0.00000 0.00000 7 PUNJAB 0.00000 1.74111 1.74111 8 RAILWAYS 0.00000 0.03585 0.03585 9 RAJASTHAN 0.00000 -0.20795 -0.20795 10 UTTAR PRADESH 56761.13297 760.11913 57521.25210 11 UTTARAKHAND 4.05472 0.01337 4.06809 12 APCPL 0.20827 0.00000 0.20827 13 NHPC 0.00000 -0.69803 -0.69803 14 NTPC 0.00000 0.00000 0.00000 15 SJVN 0.00000 -0.07099 -0.07099 16 THDC 0.00000 -0.03654 -0.03654 17 ADHPL 0.00000 0.00000 0.00000 18 EPPL 108.14017 3.10466 111.24483 19 JPVL 0.00000 6.90305 6.90305 20 LANCO 496.57923 21.92417 518.50340 21 SCL -2.70459 0.00000 -2.70459 22 ER-NR 579.61098 127.49888 707.10986 23 WR-NR 0.00000 -8.33774 -8.33774 24 Pool Balance -77561.80122 -1392.37127 -78954.17249

UPPCL, PDD J & K, EPPL & Lanco Budhil have not released any payment against Deviation charges since DSM came into effect.

Utilities that have to pay the deviation charges are requested to release the outstanding amount at the earliest.

D.3 Status of Reactive Energy (RE) Charges

As per the information received from NRLDC, the status of payment of Reactive Energy charges payable/Receivable by the utilities as on 23.02.2015 is as given below:

37


Sl. No

Constituent NET RE Charges Balance Upto 31st Mar'14

RE Charges Payable/

receivable During 2014-

15 (upto 23.02.15)

NET RE Charges Balance

as on 23.02.15

Interest on delayed

payment of RE charges

Upto Qtr 2 of 2014-15

Net Balance

1 Chandigarh -175.34 -4.93 -204.30 -209.44 -413.74 2 Delhi -193.60 0.12 -82.02 -350.99 -433.01 3 Haryana -4566.77 -168.63 -5254.97 -3021.73 -8276.7 4 H.P. -303.78 -2.06 -362.22 -221.64 -583.86 5 J&K 17069.62 984.36 19635.03 10525.38 30160.4 6 Punjab 725.66 -17.44 757.21 -428.02 329.19 7 Rajsthan -2556.21 -300.79 -3185.36 -1979.40 -5164.8 8 U.P. -8628.83 -497.42 -9931.17 -4309.68 -14241 9 Uttarakhand -12.12 6.8 -13.57 -4.49 -18.06

As on date Total outstanding of Reactive energy Charges against PDD J& K are Rs. 301.60 Cr (Principal Rs. 196.35 Cr., & Delay payment Interest Rs. 105.25Cr).

All Payable constituents are requested to release outstanding RE charges payments at the earliest.

D.4 Reimbursement of Expenditure of NRPC Sectt. for the year 2014-15 by the

members of NRPC

In the 30th NRPC meeting held on 27.02.2014, it was decided to contribute the amount of Rs.11 Lakh per member for the year 2014-15 toward reimbursing NRPC expenditure to GoI for the year 2014-15, for meeting the expenditure for meetings at Secretariat and other expenditure as approved by Chairperson, NRPC. The contribution is awaited from following utilities: S.No. Constituent Member S.No. Constituent Member

1 BSES Yamuna Power Ltd. 6 Jhajjar Power Co. Ltd.

2 Bajaj Energy Pvt Ltd. 7 PSTCL , Patiala

3 Dakshinanchal VUNL, Agra 8 Power Transmission Corp. of Uttarakhand Ltd.

4 JdVVNL, Jaipur 9 UPCL , Dehradun

5 J&K State PDC Ltd ,J&K 10 UPPTCL, Lucknow

Members are requested to expedite the contribution.

D.5 Reimbursement of Expenditure of NRPC Sectt. by the members of NRPC for the previous years

38


For reimbursing NRPC expenditure to GoI and meeting the expenditure for meetings at Secretariat and other expenditure as approved by Chairperson, NRPC, constituent members are to pay annual contribution as decided at NRPC meetings from time to time.

The contribution is awaited from following members: S.No. Constituent Member Amount Financial Year 2013-2014

1. Dakshin Haryana Bijli Vitaran Nigam Ltd

Rs.11.5 Lakh

2. Power Development Department, J&K

Financial Year 2012-2013 1. Purvanchal Vidyut Vitaran Nigam

Ltd. Rs.10 Lakh

D.6 Membership in NRPC for rotational members

Government of India, Ministry of Power under the provision of Section 2,Subsection 55 of the Electricity Act 2003 vide its resolution dated 25.05.2005 and subsequent amendments dated 29.11.2005 and 09.05.2008 established the Northern Regional Power Committee in place of erstwhile Northern Regional Electricity Board.

The amended resolution dated 9.5.2008 provides for representation by rotation for DISCOM and Generating companies as given below:

i) From each state, one of the State owned distribution companies as nominated by the State Government.

ii) One distribution company by alphabetical rotation out of the private distribution companies functioning in the region is to be represented in NRPC.

iii) A representative of the generating companies (other than central generating companies or State Government owned generating companies) having power plants in the region with installed capacity of 1000 MW or below by alphabetical rotation.

During the 25th NRPC meeting held on 24.02.2012, it was decided that NRPC Sectt should finalize the representation of State owned distribution companies by rotation based on the list of State owned distribution companies and its representation in the previous years. In the State of Haryana, Rajasthan and Uttar Pradesh there are two, three and four State owned distribution companies respectively. As per the decision in the 25th NRPC meeting held on 24.02.2012 the membership of State owned distribution companies for the year 2015-16 from the above States representation will be as follows:

39


Haryana : Dakshin Haryana Bijli Vitaran Nigam Ltd. Rajasthan : Jaipur Vidyut Vitran Nigam Ltd. Uttar Pradesh : Paschimanchal Vidyut Vitaran Nigam Ltd.

In respect of private distribution companies in Northern Region, there are three major distribution companies namely BSES Rajdhani Power Ltd, BSES Yamuna Power Ltd and Tata Delhi Power Distribution Co. Ltd mainly operating in Delhi. According to the rotation followed in previous years and alphabetical order, Tata Delhi Power Distribution Co. Ltd may be considered for membership under this category during year 2015-16.

A representation of the generating companies (other than central generating companies or State Government owned generating companies) having power plants in the region with installed capacity of 1000 MW or below is to be made by alphabetical rotation. Based on the list of such generating companies operating in the Northern Region and alphabetical order followed in the past, this year it is the turn of Everest Power Private Ltd (Malana-II HEP 2x50 MW in Himachal Pradesh) during the year 2015-16.

Regarding nomination of members from Electricity Traders, CEA has been requested to intimate the name of trader for the year 2015-16 in co-ordination with other RPCs. After receipt of the nomination of electricity traders from the CEA, the same shall be included in the membership of NRPC for year 2015-16.

For information and approval of Members.

HOSTING OF NEXT MEETINGS OF NRPC / TCC Taking into account the agreed roster for hosting of meetings, the next meetings of TCC (31st ) & NRPC (35th), which would become due in July, 2015 are to be hosted by Himachal Pradesh.

*********

40


Annex-I Status of PSS Tuning

Station U.No.(Cap.) Digital AVR provided (Y/N)

Step Test/Tuning done after

01.11.2013(Y/N)

Date on which StepTest/Tuning is done

Test Results Submitted(Y/N)

Sufficient damping (Y/N)

Remarks (See Notes below the table to understand meaning of the remark)

Singrauli 1(200) Y N

TEST STPS 2(200) Y N

TEST

3(200) Y N

TEST 4(200) Y N

TEST

5(200) Y N

TEST 6(500) N

DVR

7(500) N DVR Rihand-I 1(500) Y N

TEST

STPS 2(500) Y N

TEST Rihand-II 3(500) Y N

TEST

4(500) Y N

TEST Rihand-III 5(500) Y Y Dec-14 N

RESULT

6(500) Y Y Dec-14 N RESULT Unchahar -I 1(210) Y N

TEST

TPS 2(210) Y Y Nov-13

RESULT Unchahar -II 3(210) N

DVR

4(210) N

DVR Unchahar -III 5(210) Y N TEST

Tanda 1(110) Y N

TEST TPS 2(110) Y N

TEST

(CSGS Dedicated to UP) 3(110) Y N

TEST 4(110) Y Y Jan-15 N RESULT

Dadri 1(210) N

DVR On April-2015 NCTPS 2(210) Y Y Jan-15 N

RESULT

3(210) Y N

TEST 4(210) Y N

TEST

5(490) Y N

TEST 6(490) Y N TEST

41


Status of PSS Tuning



01.11.2013(Y/N)





BTPS 1(95) N

DVR (CSGS Dedicated to

Delhi) 2(95) N

DVR

3(95) N

DVR 4(210) Y N

TEST

5(210) Y N TEST

Anta GT 1(88.7) Y N

TEST ( planned in 2015-16)

GPS GT 2(88.7) Y N


GT 3(88.7) Y N


ST 1 (153.2) N DVR(Planned in 2015)

Auriya GT 1(111.19) N

DVR (planned in June-15)

GPS GT 2(111.19) N

DVR(planned in Oct-15)

GT 3(111.19) N

DVR(planned in Dec-15)

GT 4(111.19) N

DVR(planned in Mar-16)

ST 1(109.3) N

DVR(planned in Oct-17)

ST 2(109.3) N DVR(planned in Aug-17)

Dadri GT 1(130.19) N

DVR GPS GT 2(130.19) N

DVR

GT 3(130.19) N

DVR GT 4(130.19) N

DVR

ST 1(154.51) Y N

TEST(planned in 2017-18)

ST 2(154.51) Y Y Aug-14 N RESULT

Faridabad (GPS) GT 1(137.758) N

DVR

42





01.11.2013(Y/N)





(CSGS Dedicated to Haryana)

GT 2(137.758) N

DVR

ST 2(156.08) Y N TEST(planned in Dec-15)

IGSTPP,Jhajjar 1(500)

NO INFO 2(500)

NO INFO

3(500) NO INFO NAPS 1(220)

NO INFO

2(220) NO INFO RAPS - A (CSGS Dedicated to Raj) 2(200) NO INFO

RAPS - B 3(220)

NO INFO 4(220) NO INFO

RAPS - C 5(220)


Station U.No.(Cap.) NHPC

Baira Siul 1(60)

NO INFO (3x60) 2(60)

NO INFO

3(60) NO INFO Salal 1(115) Y N

TEST

(6x115) 2(115) Y N

TEST

3(115) Y Y Exact date is to be intimated Y

INCOMPLETE INFO


INCOMPLETE INFO


INCOMPLETE INFO

6(115) Y Y Exact date is to be intimated Y INCOMPLETE INFO

43





01.11.2013(Y/N)





Chamera - I 1(180) Y Exact date is to be intimated Y

INCOMPLETE INFO

(3x180) 2(180) Y Exact date is to be intimated Y

INCOMPLETE INFO

3(180) Y Exact date is to be intimated Y INCOMPLETE INFO

Chamera - II 1(100)

NO INFO (3x100) 2(100)

NO INFO

3(100) NO INFO Chamera - III 1(77)

NO INFO

(3x77) 2(77)

NO INFO 3(77 ) NO INFO

Uri 1(120)

NO INFO (4x120) 2(120)

NO INFO

3(120)


Tanakpur 1(31.4)

PSS Not mandatory (3x31.4) 2(31.4)

PSS Not mandatory

3(31.4) PSS Not mandatory Uri II 1(60)

NO INFO

(4x60) 2(60)

NO INFO 3(60)

NO INFO

4(60) NO INFO Dhauliganga 1(70)

NO INFO

(4x70) 2(70)

NO INFO 3(70)

NO INFO

4(70) NO INFO Dulhasti 1(130)

NO INFO

(3x130) 2(130)


44





01.11.2013(Y/N)





SEWA -- II 1(40)

PSS Not mandatory (3x40) 2(40)

PSS Not mandatory

3(40) PSS Not mandatory

Station U.No.(Cap.) BBMB 1(108) N

DVR

Bhakra (L) 2(126) N

DVR 3(108) N

DVR

4(108) N

DVR 5(126) N DVR

Bhakra (R) 6(157) Y

INCOMPLETE INFO 7(157) Y

INCOMPLETE INFO

8(157) Y

INCOMPLETE INFO 9(157) Y

INCOMPLETE INFO

10(157) Y INCOMPLETE INFO Ganguwal 1(27.99) Y N

PSS Not mandatory

2(24.20) Y N

PSS Not mandatory 3(24.20) Y N PSS Not mandatory

Kotla 1(28.94) Y N

PSS Not mandatory 2(24.20) Y N

PSS Not mandatory

3(24.20) Y N PSS Not mandatory Dehar 1(165) N

DVR

2(165) N

DVR 3(165) N

DVR

4(165) N

DVR 6(165) N DVR

Pong 1(66) N

DVR 2(66) N

DVR

3(66) N

DVR

45





01.11.2013(Y/N)





4(66) N

DVR 5(66) N

DVR

6(66) N DVR Rampur 1(68.67) Y Exact Date not given During Comissioning Y

INCOMPLETE INFO

(6x68.67) 2(68.67) Y Exact Date not given During Comissioning Y

INCOMPLETE INFO 3(68.67) Y Exact Date not given During Comissioning Y

INCOMPLETE INFO

4(68.67) Y Exact Date not given During Comissioning Y

INCOMPLETE INFO 5(68.67) Y Exact Date not given During Comissioning Y

INCOMPLETE INFO

6(68.67) NO INFO Nathpa-Jhakri 1(250)

INCOMPLETE INFO

(6x250) 2(250)

INCOMPLETE INFO 4(250)

INCOMPLETE INFO

5(250)

INCOMPLETE INFO 6(250) INCOMPLETE INFO

Allain-Duhangan 1(96)

INCOMPLETE INFO (2x96) 2(96) INCOMPLETE INFO

Tehri HPP 1(250)

NO INFO 2(250)

NO INFO

3(250)


Koteshwar HEP 1(100)

NO INFO 2(100)

NO INFO

3(100)


Station U.No.(Cap.)

46





01.11.2013(Y/N)





Delhi 1(30)

PSS Not mandatory GTs 2(30)

PSS Not mandatory

(6x30+24+24+25) 3(30)

PSS Not mandatory 4(30)

PSS Not mandatory

5(30)

PSS Not mandatory 6(30)

PSS Not mandatory

1(15) ST HRSG-1

PSS Not mandatory

1(15) ST HRSG-2

PSS Not mandatory

2(15) ST HRSG-3

PSS Not mandatory

2(15) ST HRSG-4

PSS Not mandatory

3(15) ST HRSG-5

PSS Not mandatory

3(15) ST HRSG-6 PSS Not mandatory

RTPS 1(67.5)

NO INFO 2X67.5 2(67.5) NO INFO

PRAGATI - I 1(104) GT

NO INFO 2(104) GT

NO INFO

3(122) ST NO INFO PRAGATI - III 1(216) GT

NO INFO

BAWANA 2(216) GT

NO INFO 3(216) GT

NO INFO

4(216) GT

NO INFO 1(253.6) ST

NO INFO

2(253.6) ST NO INFO Haryana 1(117.8)

NO INFO

PTPS 2(110)

NO INFO 3(110)

NO INFO

4(110)

NO INFO

47





01.11.2013(Y/N)





5(210)

NO INFO 6(210)

NO INFO

7(250)


DCRTPP Yamuna Nagar 1(300)

NO INFO (2x300 ) 2(300) NO INFO

RGTPP HISSAR 1(600)

NO INFO (2x600 ) 2(600) NO INFO

CLP 1(660)

NO INFO Jhhajhar 2(660) NO INFO PSPCL 1(110)

NO INFO

GNDTPS(Bhatinda) 2(110)

NO INFO 3(120)

NO INFO

4(120) NO INFO ROPAR TPS 1(210)

NO INFO

(6x210) 2(210)

NO INFO GGSSTP 3(210)

NO INFO

4(210)

NO INFO 5(210)

NO INFO

6(210) NO INFO GHTP LM'bat ( 2 x

210)+( 2 x 250) 1(210)

NO INFO

2(210)

NO INFO 3(250)

NO INFO

4(250) NO INFO

Station U.No.(Cap.) Rajasthan 1(110) N

DVR

KTPS 2(110) Y Y 16/09/2014 N

RESULTS

48





01.11.2013(Y/N)





3(210) Y Y 16/09/2014 N

RESULTS 4(210) Y Y 16/09/2014 N

RESULTS

5(210) Y Y 16/09/2014 N

RESULTS 6(195) Y Y 16/09/2014 N

RESULTS

7(195) Y Y 16/09/2014 N RESULTS RAMGARH GAS CCPP 1(38.5) GT

PSS Not mandatory

2(37.5)GT

PSS Not mandatory 3(110)GT

NO INFO

1(37.5) ST

PSS Not mandatory 2(50) ST PSS Not mandatory

SURATGARH TPS 1(250)

NO INFO 2(250)

NO INFO

3(250)

NO INFO 4(250)

NO INFO

5(250)


DHOLPUR GAS CCPP 1(110) GT Y Exact Date not given During Comissioning

INCOMPLETE INFO 2(110) GT Y

During Comissioning

INCOMPLETE INFO

3(110) ST Y During Comissioning INCOMPLETE INFO Kalisindh TPP 1(600)

NO INFO

2(600) NO INFO GIRAL 1(125) Y Exact Date not given During Comissioning

INCOMPLETE INFO

2(125) Y Exact Date not given During Comissioning INCOMPLETE INFO CHHABRA TPS 1(250) Y Exact Date not given During Comissioning

INCOMPLETE INFO

2(250) Y Exact Date not given During Comissioning

INCOMPLETE INFO 3(250) Y Exact Date not given During Comissioning

INCOMPLETE INFO

4(250) NO INFO BARSINGSAR LTPS 1(125)

NO INFO

NLC 2(125) NO INFO

49





01.11.2013(Y/N)





KAWAI (Adani) 1(660)


RAJWEST Power 1(135)

NO INFO (8x135) 2(135)

NO INFO

3(135)

NO INFO 4(135)

NO INFO

5(135)

NO INFO 6(135)

NO INFO

7(135)


Station U.No.(Cap.)

UPPCL 1(210) Y Y 06.01.15 Y Y ANPARA 2(210) Y Y 06.01.15 Y Y (3x210+2x500) 3(210) Y Y 05.01.15 Y Y 4(500) Y Y 07.12.14 Y Y 5(500) Y Y 17.08.14 Y Y

1(50) OBRA 2(50)

7(94) N N

DVR 8(94)

NO INFO

9(200) Y N

TEST 10(200) Y N

TEST

11(200) Y N

TEST 12(200) Not Clear N

INCOMPLETE INFO

13(200) Not Clear N INCOMPLETE INFO PARICHHA 1(110) Y N

TEST

2(110) Y N

TEST (2x110+2x210) 3(210) Y N

TEST

4(210) Y N

TEST

50





01.11.2013(Y/N)





5(250) Y N


PANKI 3(105) N N

DVR 4(105) N N DVR

H'GANJ 5(60) N N

DVR 7(120) Y N

TEST

8(250) Y N


Station U.No.(Cap.) ROSA TPS ( IPP ) 1(300)

NO INFO

( 3x300 ) 2(300)

NO INFO 3(300)

NO INFO

4(300) NO INFO ANPARA - C( IPP ) 1(600) NO INFO

LANCO 2(600) NO INFO

NOTE: Meaning of remarks

TEST: Step Test need to be carried out till October 2015.

DVR: Plan for providing DVR to be submitted.

NO INFO: No information has been submitted by the Generating Station.

RESULT: Test results need to be submitted by the Generating Station

INCOMPLETE INFO: Complete information need to be submitted.

51


Annexure-II

Procedure for Transmission Elements Outage Planning in

Northern Region

March 2015

The procedure aims to streamline the process of transmission outage coordination between SLDCs, NRLDCs, NLDC, NRPC and Indenting Agencies

52


Procedure for Transmission Elements Outage Planning in Northern Region 1. Introduction

Reliable operation of the All India grid is important from the view point of Quality Of Service (QoS) to the customers and other stakeholders. Proper co-ordination of transmission outages in the system is one of the key aspects to ensuring reliability. Outages in the transmission network could either be on account of planned maintenance activities or construction related activities or any emergency conditions arising in the field. Proper coordination of transmission element outage is important mainly due to the following factors:

i. Reliability of operation of the All India grid ii. Certainty to the electricity markets. iii. Proper crew resource mobilization at the work sites to ensure that outage time is minimized. iv. Proper coordination of works by different entities to ensure that outage time is optimised.

Outage Coordination has been one of the important functions of Regional Power Committees (RPCs), Regional Load Despatch Centres (RLDCs) and National Load Despatch Centre (NLDC) and is the first stage of operational planning. As per Indian Electricity Grid Code (IEGC), the responsibility to undertake planning of outage of transmission system has been assigned to RPCs. The outages of the inter-state transmission lines and intra state elements which are important for the region are being coordinated by RLDCs. In the cases where the outages may have an impact across two or more regions, coordination is in consultation with NLDC. The relevant clauses of IEGC in this regard are quoted below: “2.4.2 The following functions which go to facilitate the stability and smooth operation of the systems are identified for the RPC: ………… (e) To undertake planning of outage of transmission system on annual / monthly basis.” “2.3 Role of RLDC 2.3.1.1The Regional Load Despatch Centre shall be the apex body to ensure integrated operation of the power system in the concerned region” “2.2 Role of NLDC …….. (f) Coordination with Regional Power Committees for regional outage schedule in the national perspective to ensure optimal utilization of power resources.” 2. Objective

53


At present, planned outages are being discussed in respective Operation Coordination Committee (OCC) meeting of RPCs and availed based on the actual grid conditions and/or any changes requested by transmission system owner or transmission element outage indenting agency. The approval of planned as well as emergency outages in the transmission network level in real time is being coordinated by RLDCs and NLDC based on system conditions. The procedure aims to streamline the process of outage coordination between SLDCs, RLDCs, NLDC, RPCs, owners of transmission assets and transmission element outage Indenting Agencies. As outage planning is an important part of operational planning, multi-layered checks would help in ensuring reliability of the power system. These checks need to be at the following levels:

• Due diligence between the agencies involved in the transmission asset maintenance through bilateral discussion.

• Studies, if required, prior to approval of outages sought Operation Co-ordination sub-Committee of RPCs

• Off-line simulations and planning at RLDCs/NLDC level

• Real time check at RLDCs/NLDC level

3. Scope

The procedure is applicable to NRPC, NRLDC, NLDC, SLDCs, STUs, load serving entities and Indenting Agency. It would be applicable once the annual outage plan is finalized by 31st December of each year for the next financial year by the NRPC as per the IEGC. 4. Definitions

4.1. Approving Load Despatch Centre: The Load Despatch Centre responsible for approving any transmission outage shall be called Approving Load Despatch Centre.

4.2. Consenting Load Despatch Centre: The agency whose consent is required by Approving Load Despatch Centre for approving any outage shall be called Consenting Load Despatch Centre.

4.3. Indenting Agency: The agency which gives the requisition for outage of any transmission element shall be called Indenting Agency. Any of the following may request for outage of any transmission elements:

(a) CTU

54


(b) STUs

(c) Transmission Licensees

(d) Generating Companies

(e) Distribution company

4.4 NLDC oversight transmission assets: All inter-national transmission lines and inter-regional transmission lines together with all 765 kV AC lines, HVDC lines and other lines which significantly influence power flow on inter-regional transmission lines shall be treated as NLDC oversight transmission asset. List of such lines is enclosed at Annex- I. NLDC shall review and update the list of such assets relevant to Northern Region in consultation with OCC and upload the same on its website.

4.5 NRLDC oversight transmission assets: All transmission assets under following categories shall be treated as NRLDC oversight transmission assets.

(i) Category A: Transmission elements at 400 kV and above.

(ii) Category B: Transmission elements at 132 kV and above level

emanating from ISGS.

(iii) Category C: Transmission elements at 132 kV and above which are

inter-regional in nature.

(iv) Category D : Transmission elements at 132 kV level with one end in

a State while other end in another State.

List of such lines is enclosed at Annex-II. NRLDC shall review and update the list of such assets in consultation with OCC and upload the same on its website.

4.6 Words and expressions used in this procedure and not defined herein but defined in the Electricity Act, 2003 (Act) or Indian Electricity Grid Code (IEGC) shall have the meaning assigned to them under the Act or IEGC.

5. Procedure for discussing transmission outages in OCC meeting.

55


5.1. Indenting Agency shall submit the proposed shutdown for NLDC oversight transmission assets for the next calendar month latest by 5th day of the current month to NRPC Secretariat as per Format IA / Format IB. The Intending Agency shall also inform the same to NLDC and other relevant RPC Secretariats.

5.2. Indenting Agency shall submit the proposed shutdown for NRLDC oversight transmission assets for the next calendar month latest by 8th day of the current month to NRPC Secretariat as per Format IA / Format IB.

5.3. The indenting agency shall carry out an internal screening of its outage plan centrally to avoid multiple outages in the same corridor simultaneously. Bilateral discussion between the agencies involved may also be done to minimize outage duration before submitting the outage plan to NRPC Secretariat.

5.4. NRPC Secretariat shall compile all the received proposals for NLDC oversight transmission assets and NRLDC oversight transmission assets separately and put up the same on its website by 5th day of the month and 12th day of the month respectively.

5.5. If required, system studies will be carried out to facilitate discussions in the OCC meeting.

5.6. The requests for transmission outages shall be considered by OCC keeping in view compliance to n-1 criteria for the relevant corridor. Based on decisions taken by the OCC, a list of approved transmission outages with the precautions to be taken shall be prepared. NRPC would endavour to schedule all their OCC meetings between 10th to 20th day of the month.

5.7. NRPC Secretariat shall upload the list of approved transmission outages on NRPC website within 3 working days of the OCC meeting.

5.8. Any shutdown proposal which requires approval of another RPC shall be considered approved only if it is approved by the OCC of NRPC as well as that of other RPC.

56


6. Responsibility of approval for transmission outages approved by OCC

Once the OCC approves the monthly outage plan, the responsibility of approval of outages shall be as under:

Sl.No Type of asset Consenting Load Despatch Centre

Approving Load Despatch Centre

1 NLDC oversight transmission asset

NRLDC NLDC

2 NRLDC oversight transmission asset (excluding lines covered under Sl no.1)

SLDCs NRLDC

3 Intra-state line (excluding lines covered under Sl no. 1 and 2

SLDC concerned SLDC concerned

7. Procedure for approval of outage on D-3 basis

7.1. Request for outages which are approved by OCC must be sent by the indenting agency of the transmission asset at least 3 days in advance to respective RLDC by 1000 hours as per Format II. (For example, if an outage is to be availed on say 10th of the month, the indenting agency would forward such requests to the concerned RLDC on 7th of the month by 1000 hours.)

7.2. In case the request for transmission element outage is not received within the timeline prescribed above, it will be assumed that the indenting agency is not availing the outage. However, indenting agency is duty bound to inform NRLDC at least 3 days in advance, if it is not availing the OCC approved outage. .

7.3. Approval of Outage where Approving Authority is NLDC

7.3.1. NRLDC shall forward the request for shutdown along with their consent and observation as per Format III to NLDC/other concerned RLDCs with clear observations regarding possible constraints / contingency plan and consent including study results by 1000 hours of

57


D-2 day. Other concerned RLDCs would forward their observations/consent/reservations by 1600 hours of D-2.

7.3.2. NLDC shall approve the outage along with the clear precautions/measures to be observed during the shutdown and inform all concerned RLDCs.

7.3.3. The proposed outages shall be reviewed on day ahead basis depending upon the system conditions and the outages shall be approved/refused latest by 1200 Hrs of D-1 day. A suggested format for approval/refusal of outage is enclosed as Format IV.

7.3.4. In case the outage is approved, precautions/measures to be observed during the shutdown shall also be stated. In case of refusal, clear reasons shall be stated by the NRLDC/NLDC.

7.3.5. Outages impacting the transfer capability of more than one corridor shall not be allowed simultaneously.

7.4. Approval of Outage where Approving Authority is NRLDC

7.4.1. In case the indenting agency falls in control area of a state, the request for transmission element outage shall be submitted to respective State Load Despatch Centre (SLDC). The SLDC shall forward the request for shutdown along with their consent and observation as per Format III to NRLDC.

7.4.2. In all other cases, the request for transmission element outage shall be submitted to NRLDC.

7.4.3. NRLDC shall study the impact of proposed outages and approve / refuse the outage latest by 1200 Hrs of D-1 day. A copy of the approval / refusal shall also be sent to NLDC (for 400 kV and above lines). A suggested format for approval / refusal of outage is enclosed as Format IV.

7.4.4. In case the outage is approved, precautions/measures to be observed during the shutdown shall also be stated. In case of refusal, clear reasons shall be stated by the SLDCs/RLDC

58


7.5. Approval of Outage where Approving Authority is SLDC

SLDC shall study the impact of proposed outages on the system and approve the outage latest by 1200 Hrs of D-1 day. The Format IV as suggested above can be used for approval / refusal of outage.

7.6. In case of any system constraint or any other reason, Approving Authority may decline the proposed outage by giving the reasons for the same and tentative dates for the shutdown.

7.7. An approved outage may not go through because of following reasons:

(a) Indenting Agency may chose not to avail the approved outage in real time without prior intimation to NRLDC or with intimation after 1000 Hrs of D-1.

(b) Indenting Agency may chose not to avail the approved outage in real time with prior intimation to NRLDC on latest by 1000 Hrs of D-1.

(c) Approved outage could not be allowed by NRLDC in real time due to system conditions.

In cases (b) and (c) above, NRLDC shall endeavour to schedule the approved outage in consultation with Indenting Agency. However, in case (b) above, priority for other outages approved by OCC and emergency outage requests shall be higher. In case (a) above, if Indenting Agency desires to avail shutdown, the request to this effect will have to be made for consideration in the next OCC meeting.

7.8. A list of all approved outages for the next day must be available in the NRLDC/NLDC control room by 1900 hours with a copy of the study results and special precautions, if any. This would be studied by the night shift engineers so that the outage can be facilitated the next day morning.

8. Approval of Emergency Outages

8.1. All outages which are not approved in the OCC meeting but having impact on human and equipment safety and/or to meet any other emergency requirement or special conditions shall be considered under Emergency Outage category. NRLDC would bring to the notice of

59


OCC the emergency shutdowns approved by NRLDC in the previous month.

8.2. The request for emergency outage shall be submitted along with the details like nature of emergency, impacts due to emergency situation, reasons and associated facts for not considering in the outage planning process.

8.3. Emergency outages shall be allowed subject to system conditions and its severity. In this case, if required, planned outage may be deferred, if possible.

8.4. Emergency outages shall be allowed immediately or within the short possible time, based on the severity of the emergency and system condition on instance to instance basis.

9. Opportunity Shutdowns

9.1 It is desirable to maximise transmission availability by utilizing opportunity shutdowns i.e. other agency/entities should also plan their work on a transmission element when shutdown for the same has been requested by an agency/entity. However, intention to avail opportunity shutdown should be indicated and got approved by OCC or a request for the same should be submitted to NRLDC on D-3 basis.

9.2 If approved shutdown is not availed by the Indenting Agency, opportunity shutdown shall not be given in real time.

9.3 If an entity desires to carry out the short maintenance work on the transmission elements under forced outage due to system constraints they may apply to NRLDC in real time. NRLDC may approve the shutdown depends upon the real time system condition.

10. Availing Outages in real time

10.1. The agencies involved shall ensure availing of outages as per the approved schedule time.

60


10.2. On the day of outage, the outage availing agency shall seek the code for availing outage from NRLDC /NLDC (wherever applicable). The agencies involved shall endeavour to avail the outage within 15 minutes of availing the code but not later than 30 minutes. In case, due to any contingency, the outage could not be availed within 30 minutes, a fresh code needs to be obtained by all concerned agencies stating the reason there of. Record of scheduled and actual time of outage and restoration shall be maintained at NRLDC/NLDC.

10.3. NRLDC shall prepare a monthly statement of scheduled and actual time of outage and restoration and forward the same to NRPC Secretariat latest by 05th day of the next month with a copy to NLDC. The format is enclosed as Format V A / Format V B.

10.4. SLDCs shall prepare a monthly statement of scheduled and actual time of outage and restoration and forward the same to NRPC Secretariat latest by 05th day of the next month with a copy to NRLDC. The Format V A / Format V B as suggested above can be used for sending the report to NRPC Secretariat.

11. Restoration of service

11.1. All effort shall be made by the Indenting agency to restore the service within approved time period.

11.2. On completion of the outage work, the Indenting Agency shall seek the code from NRLDC for restoration of elements under outage. The agencies involved shall endeavour to restore the service within 15mintues of availing the code but not later than 30 minutes. In case, due to any contingency, restoration could not be done within 30 minutes, a fresh code needs to be obtained by all concerned agencies stating the reason thereof.

11.3. In case of extension of a shutdown, the Indenting Agency would furnish the reasons of extension, and expected restoration time to NRLDC/concerned SLDC at least one hour before the scheduled restoration time.

61


11.4. Under such circumstances SLDCs/NRLDC/NLDC shall review the impact of such delay and would convey approval or disapproval of the extension of shutdown, as the case may be.

11.5. In case of repeated delay in restoration of service by any agency, the same shall be reported by SLDCs/NRLDC/NLDC to NRPC.

12. Miscellaneous

12.1 While submitting reasons for seeking outages, elaborate explanation taking care of possible queries should be furnished.

12.2 In case outage of transmission element is not required but other accessories such as certain protection is to be disabled, request should be made to NRLDC preferably before 1000 Hrs on D-3 but not later than 1000 Hrs. of D-1.

12.3 Some minor works such as relay retrofitting, for which actual date of shutdown depends on OEM Engineer, the utility concerned would submit list of such works planned during next calendar month prior to OCC meeting. To avail the shutdown for works mentioned in the list, the Indenting Agency shall submit request to NRLDC before 1000 Hrs on D-3.

12.4 In case shutdown is required to facilitate construction of another transmission line and the start date of the shutdown cannot be foreseen with reasonable accuracy, the Indenting Agency shall indicate a window of ±3 days in the start date while requesting the shutdown.

12.5 The multiple outages of the transmission element for the same work during the year may be avoided.

12.6 Entities/agencies shall endeavour to avail the outage as per the Annual outage plan submitted to NRPC. Any deviation from Annual outage plan should be informed to NRPC.

12.7 When the web-based application for transmission outage planning and approval becomes operational, request for outages would be submitted through this application in accordance with time line contained in this procedure. Till such time, the outage requests shall be submitted in the prescribed format through email at [email protected].

62


List of Formats

1 Format IA Request For Transmission line Outage for consideration in OCC meeting

Indenting Agency

NRPC

2 Format IB Request For Bus, Bay, ICTs, Reactor, FACTS, FSCs, SVCs etc Outage for consideration in OCC meeting

Indenting Agency

NRPC

3 Format II Request for availing Transmission Element Outage approved by OCC

Indenting Agency

NRLDC/SLDC

4 Format III Forwarding of request received for Transmission Element Outage

SLDC/NRLDC

NRLDC/NLDC

5 Format IV Approval / refusal of Outage

RLDC / NLDC Indenting Agency/NRLDC

6 Format V A Monthly Shutdown Report For Transmission Lines

SLDC/NRLDC NRPC

7 Format V B Monthly Shutdown Report For For Bus, Bay, ICTs, Reactor, FACTS, FSCs, SVCs etc

SLDC/NRLDC NRPC

63


Annex- III Actual Power Supply Position of Northern Region for the period from November, 2014 to

February, 2015. Revised Power Supply Position of Northern Region

November, 2014

State

Peak Demand

Peak Met

Surplus/Deficit (-)

Energy Requirement

Energy Availability

Surplus/Deficit (-)

MW MW MW % MU/day MU/day MU/day %

CHANDIGARH 190 190 0 0.0 3.31 3.31 0.00 0.0

DELHI 3408 3408 0 0.0 58.19 58.15 -0.04 -0.1

HARYANA 6345 6340 -5 -0.1 106.32 106.25 -0.07 -0.1

H.P. 1403 1403 0 0.0 24.04 23.93 -0.11 -0.5

J&K 2455 1964 -491 -

20.0 48.17 38.54 -9.62 -20.0

PUNJAB 5626 5626 0 0.0 95.54 95.43 -0.11 -0.1

RAJASTHAN 9525 9525 0 0.0 193.28 193.28 0.00 0.0

U.P. 12744 10694 -

2050 -

16.1 266.09 220.64 -45.45 -17.1

UTTARAKHAND 1828 1748 -80 -4.4 32.30 31.28 -1.02 -3.1

NFF/Railway 100 100 0 0.0 2.26 2.26 0.00 0.0

REGION 40595 39070 -

1525 -3.8 829.49 773.07 -56.42 -6.8 December, 2014

State

Peak Demand

Peak Met

Surplus/Deficit (-)

Energy Requirement

Energy Availability

Surplus/Deficit (-)


CHANDIGARH 252 252 0 0.0 3.70 3.70 0.00 0.0

DELHI 4271 4271 0 0.0 62.13 61.93 -0.20 -0.3

HARYANA 6480 6480 0 0.0 115.21 113.79 -1.43 -1.2

H.P. 1417 1397 -20 -1.4 24.57 24.32 -0.25 -1.0

J&K 2554 2043 -511 -

20.0 52.13 41.70 -10.43 -20.0

PUNJAB 5808 5808 0 0.0 100.30 100.30 0.00 0.0

RAJASTHAN 10642 10642 0 0.0 200.33 200.33 0.00 0.0

U.P. 13439 11779 -

1660 -

12.4 264.30 222.63 -41.67 -15.8

UTTARAKHAND 1873 1873 0 0.0 33.30 32.72 -0.58 -1.7

NFF/Railway 100 100 0 0.0 2.11 2.11 0.00 0.0

REGION 45425 42592 -

2833 -6.2 858.08 803.52 -54.56 -6.4

64


Revised Power Supply Position of Northern Region

January, 2015

State

Peak Demand

Peak Met

Surplus/Deficit (-)

Energy Requirement

Energy Availability

Surplus/Deficit (-)


CHANDIGARH 252 252 0 0.0 4.02 4.02 0.00 0.0

DELHI 4405 4405 0 0.0 67.32 67.27 -0.05 -0.1

HARYANA 6720 6720 0 0.0 113.59 113.56 -0.03 0.0

H.P. 1417 1403 -14 -1.0 24.67 24.60 -0.07 -0.3

J&K 2393 2006 -387 -

16.2 51.74 41.75 -9.99 -19.3

PUNJAB 5347 5347 0 0.0 94.01 94.01 0.00 0.0

RAJASTHAN 10179 10179 0 0.0 194.42 194.42 0.00 0.0

U.P. 12024 11644 -380 -3.2 267.31 225.83 -41.49 -15.5

UTTARAKHAND 1930 1930 0 0.0 35.90 35.13 -0.77 -2.1

NFF/Railway 100 100 0 0.0 2.12 2.12 0.00 0.0

REGION 42381 40774 -

1607 -3.8 855.10 802.71 -52.39 -6.1

Provisional Power Supply Position of Northern Region February, 2015

State Peak

Demand Peak Met

Surplus/Deficit (-)

Energy Requirement

Energy Availability

Surplus/Deficit (-)


CHANDIGARH 204 204 0 0.0 3.48 3.48 0.00 0.0

DELHI 3847 3847 0 0.0 60.28 60.25 -0.03 0.0

HARYANA 6692 6692 0 0.0 113.63 113.61 -0.02 0.0

H.P. 1422 1422 0 0.0 24.52 24.40 -0.12 -0.5

J&K 2377 2021 -356 -

15.0 47.44 40.33 -7.11 -

15.0

PUNJAB 5720 5720 0 0.0 89.02 89.02 0.00 0.0

RAJASTHAN 10095 10095 0 0.0 200.32 200.32 0.00 0.0

U.P. 12362 11387 -975 -7.9 262.77 228.85 -33.93 -

12.9

UTTARAKHAND 1910 1910 0 0.0 34.32 33.67 -0.64 -1.9

REGION 39764 38043 -

1721 -4.3 835.78 793.94 -41.84 -5.0

65


Annex-IV

Consumption Growth- (%) for the period from September, 2013 to September, 2014.

State Jan Feb Mar April May June July Aug Sep Oct Nov Dec Jan

2014 2014 2014 2014 2014 2014 2014 2014 2014 2014 2014 2014 2015

PUN -4.85 8.10 -1.71 -3.03 -13.42 17.52 9.70 18.45 -10.36 0.64 12.69 3.18 1.88

HAR 5.83 19.17 -8.07 2.54 -6.45 7.21 4.93 24.31 -0.21 11.58 9.97 9.33 10.02

RAJ 9.24 20.05 2.98 10.98 6.44 21.00 25.19 21.07 1.56 26.50 19.43 10.62 9.03

DELHI 1.44 4.34 -0.13 -3.09 -4.65 8.03 8.08 14.16 -0.46 1.26 2.70 6.51 0.87

UP 7.05 14.73 8.55 16.91 5.52 19.02 4.95 7.42 2.88 9.33 5.30 5.44 4.79

UTT 11.28 14.32 4.95 2.37 -2.41 16.35 4.38 8.57 6.39 -1.09 9.57 8.32 7.59

HP 4.79 3.30 7.04 0..95 3.00 2.43 0.90 5.99 0.30 -1.75 6.69 -1.55 5.02

J & K 6.43 6.76 -0.50 6.42 -1.56 -2.10 1.03 10.80 -19.00 2.63 4.78 9.02 7.29

Regional 5.39 13.88 2.20 7.06 -0.95 14.69 9.88 15.43 -1.42 9.77 10.22 7.15 6.13

66


Annex-V

Load relief from SPS Operation

S. No. SPS Date Time

As per PMU data Planned Load relief (MW)

% of planned

load relief

Rise in frequency

(Hz)

Probable load relief (MW)

1 765kV Agra-Gwalior

21-Dec-14 19:46hrs 0.012 66 520 23


22-Dec-14 19:52hrs 0.035 192.5 520 6


24-Dec-14 09:45hrs 0.015 82.5 520 18


24-Dec-14 20:34hrs 0.074 407 520 45


25-Dec-14 18:03hrs 0.046 253 520 32


26-Dec-14 19:47hrs 0.057 313.5 520 2


27-Dec-14 20:30hrs 0.026 143 520 38


30-Dec-14 17:12hrs 0.014 77 520 30

9 HVDC Rihand-Dadri

18-Jan-15 07:42hrs 0.027 149 520 29

10 HVDC Rihand-Dadri

23-Jan-15 07:55hrs 0.018 99 520 19


02-Feb-15 08:44hrs -- -- 520 --


05-Feb-15 19:32hrs 0.032 176 520 34


13-Feb-15 07:57hrs 0.02 110 520 21


13-Feb-15 08:18hrs Nil Nil 520 0


13-Feb-15 11:35hrs Nil Nil 520 0


13-Feb-15 13:51hrs 0.021 116 520 22

67


Annex-VI

Organisation Chart

Head-Load Despatch Centre

Divisional HeadMarket Operation

Divisional HeadServices

Divisional HeadSystem Operation

Shift Charge Manager

(Real-time)

Chief-Reliability

Coordinator

Chief-Ancillary Services

Executives (Real-time)System Security

Supervision & ControlContingency Analysis

Online simulationCongestion managementCoordination w ith SLDCs

ExecutivesEnergy Balance

Primary ResponseReactive Capability

Blackstart exercisesRamping, OverloadEnergy eff iciencyLoss optimization

Reserves

ExecutivesOperational planning, strategy

Outage coordination, simulationsTransfer Capability assessment

Grid event analysis, DocumentationEnergy Management System

Reliability Indices, availability certif icationFeedback for capacity augmentation

Dispatcher Training SimulatorMananagement Information SystemCoordination Committees, Feedback

Divisional HeadSystem Logistics

Chief-Visualization andDecision Support

Chief-Information Technology

ExecutivesData Acquisition System

Energy Management SystemSoftw are, Hardware,TelemetryOnline database developmentOnline database maintenance

Technology ManagementApplied research and development

ExecutivesSoftw are development

MaintenanceCommunication systemTechnology management

Website, Intranet Know ledge portal

Chief-Open Access

and scheduling

Chief-Settlement

System

Chief-Pool

Accounts

Executives (Real-time & Offline)

Scheduling, Merit orderMarket Information

Open AccessPow er ExchangesMarket analysis

Market surveillanceRenew able Energy

ExecutivesMetering design,

Maintenance Testing

Energy data collectionValidation & Processing

Settlement

ExecutivesAccounting

Billing, Collection

DisbursementFees & Charges

Chief-Establishment

Services

Chief-Regulatory

Affairs

Chief-Human Resource

Training/Certif ication

ExecutivesProcurement, OutsourcingPay roll, claims, Incentives

Canteen, ConveyancePow er Supply, House keeping

Ergonomics, Horticulture

ExecutivesTariff , Government Policy

Discussion paperPetition, hearing, responses

Feedback to ERCs

ExecutivesRecruitment, Training

Certif ication, Higher studiesProfessional engagementLibrary, Mentoring, Ethics

Occupational health Public Relations

Corporate communicationCorporate Social Responsibility

ORGANIZATION CHART FOR A TYPICAL LOAD DESPATCH CENTRE

68


Manpower Requirement at LDC Top management- Expert level (5) S. No Position Department Level No. 1 Head- LDC -- E8- E10 1 2

Divisional Head- System Operation System Operation

E7- E8 1

3 Divisional Head- Market Operation

Market Operation

E7- E8 1

4 Divisional Head- System Logistics Logistics E7- E8 1 5 Divisional Head- Establishment Services Services E7- E8 1 Middle management- Proficient level (15) S. No Position Department Level No. 6

Shift Charge Manager- Real-time System Operation

E6 - E7 5

7 Chief- Reliability Coordinator System Operation E6- E7 1 8 Chief- Grid Ancillary Services Coordinator System Operation E6- E7 1 9 Chief- Open Access & Scheduling

Coordinator Market Operation

E6- E7 1

10 Chief- Settlement System Coordinator

Market Operation

E6- E7 1

11 Chief- Pool Account Administrator

Market Operation

E6- E7 1

12 Chief- Logistics (SCADA) Logistics E6 - E7 1 13 Chief- Logistics (IT & Communication) Logistics E6 – E7 1 14 Chief- Establishment Services Services E6 - E7 1 15 Chief- Regulatory Affairs Services E6- E7 1 16 Chief- Human Resources Services E6- E7 1 Executives-Basic level [Real-time]- (15) S. No Position Department Level No. 17

Executive- Power System Security System Operation

E2 - E5 5

18 Executive- Resource Scheduling Market Operation E2 – E5 5 19 Executive- Open Access Market Operation E2 – E5 5 Executives- Basic level [Off-line] – (34) S. No

Position Department Level No.

69


S. No

Position Department Level No.

20 Executive- Grid Ancillary Services

System Operation

E2 - E5 1

21 Executive- Analysis & Offline Simulations

System Operation

E2 – E5 1

22 Executive- Energy Management System

System Operation

E2 – E5 1

23 Executive- System Protection Coordination

System Operation

E2 – E5 1

24 Executive- Planned Outage Coordination

System Operation

E2 – E5 1

25 Executive- Dispatcher Training Simulator

System Operation

E2 – E5 1

26 Executive- Documentation

System Operation

E2 – E5 1

27 Executive- Power System Information System Operation E2 – E5 1 28 Executive- Coordination Committee System Operation E2 – E5 1 S. No Position Department Level No. 29 Executive- Metering System Design Market Operation E2 – E5 1 30 Executive- Metering System Maintenance Market Operation E2 – E5 1 31 Executive- Meter data Collection Market Operation S1 – E2 1 32 Executive- Meter data Validation & Processing Market Operation S1 – E2 1 33 Executive- Energy Accounting Market Operation E2 – E5 2 34 Executive- Settlement Market Operation E2 – E5 1 35 Executive- Pool Account Administration Market Operation E2 – E5 1 36 Executive- SCADA Hardware Logistics E2 – E5 1 37 Executive- SCADA Software Logistics E2 – E5 1 38 Executive- Telemetry Logistics E2 – E5 1 39 Executive- Online Database Development Logistics S1 – E2 1 40 Executive- Online Database Maintenance Logistics E2 – E5 1 41 Executive- IT software development Logistics E2 – E5 1 42

Executive- IT systems maintenance Logistics S1-

E2 1

43 Executive- Applied R & D Logistics E2 – E5 1 44 Executive- Communication System Logistics S1 – E2 1 45 Executive- LDC Fees and Charges Services E2 – E5 1 46 Executive- Human Resource Management Services E2 – E5 1 47 Executive- Law and Regulatory Affairs Services E2 – E5 1 48 Executive- Procurement & Outsourcing Services E2 – E5 1 49 Executive- Administration (Library, Canteen, Services E2 – E5 1

70


DG etc.)

50 Executive- Establishment (Payroll, claims, incentives) Services S1 – E2 2

51 Executive- CSR, Renewables, Energy Efficiency Services E2- E5 1

Total executives in a typical LDC: 60 - 70 Total estimated number for all India with 39 control centres: 2250 - 2750 Assumptions: LDCs would focus on their core activities and outsource the routine and non-core activities to improve their productivity.

71


Annex-VII

Manpower deployed in LDCs in NR

S.No. Divisions UP HARYANA RAJASTHAN HP PUNJAB DELHI

Number of executives Sanctioned Working Sanctioned Working Sanctioned Working Sanctioned Working Sanctioned Working Sanctioned Working

1 System Operation

53 37 29 10 NA 21

11 11

10 23

2 Market Operation

27 13 7 11 NA 16 4 4

3 System Logistics

15 3 11 12 NA 25 10 9

4

Sub-total 95 53 47 33 NA 62 24

5 Services & LDC and Divisional heads

19 3 8 2 NA 5 3 1

6 Grand Total

114 56 55 35 NA 67 27 37

72


Annex-VIII Guidelines for planning, procurement and deployment of Emergency Restoration

System

73


74


75


76


77


Annex-X Extract of CEA’s Grid Connectivity Standards

78


79


Annex-X Status of rectification of protection related deficiencies covered under Basic

Protection Audit (BPA)

S.No. Utility No. of sub-stations covered under BPA

Expected Completion

Remarks

1 UPPTCL 21 April, 2015 220 kV Chinhat-completed. Rest up to April, 2015

2 UPRVUNL 4 April, 2015 Anpara – Mar.,2015 Obra’A’ – April,2015 Obra’B’ – completed. Harduaganj–Mar.,2015

3 RRVPNL 8 July, 2015 Rectification of seven sub-stns completed. 400 kV Ratangarh S/s is expected to be completed by July, 2015.

4 RRVUNL 2 Suratgarh-Completed. Kota - March 2015

Suratgarh – Rectification Completed RRVUNL filed a petition to Hon’ble Commission vide Petition no. 448/RC/2014 seeking extension of time for completion of rectification work related to protection system at KSTPS in respect of Commission’s direction dtd. 21.02.2014 in the Petition no.220/MP/2012. Hon’ble Commission has allowed completion of rectification by 31.03.2015. NRPC has also been directed by the Commission to ensure task is completed latest by 31.03.2015.

5 HVPNL 1 Completed. Completed.

6 HPGCL 3 March, 2015 The Action Taken Report submitted lastly by HPGCL vide their Memo no. Ch-39/SYD-52 dt. 15.09.14. Latest status is not known.

7 PSTCL 3 February, 2015 February, 2015 8 PSPCL 1 December,

2014

PSPCL had submitted the status of rectification of removal of deficiencies vide Memo. No. 7890 dt. 07.11.14 during the 33rd NRPC meeting. Latest status is not known.

9 DTL 1 March, 2015 Up to March, 2015. 10 HPSEB

Ltd. 1 March, 2015 Up to to March,2015

11 PTCUL 2 November, 2014 for Kashipur (Based on last Report dt. 29.05.14)

PTCUL vide last letter no. 206/PTCUL/OCC dt.09.05.14 had informed that rectification had been completed at Rishikesh and Kashipur by November, ’14. Latest up-dates from PTCUL is not available.

12 UJVNL 1 Target Status not known.

80


S.No. Utility No. of sub-stations covered under BPA

Expected Completion

Remarks

completion not available

13 PDD, J&K 3 Status of progress is not submitted. Target completion not known.

As informed during 33rd NRPC meeting that deficiencies where procurement was not involved have been completed and other works where procurement is involved are yet to be taken up. Latest status is not known.

14 BBMB 7 May, 2015 As per Progress report of January, ’15, the rectification work shall be completed by May, 2015.

15 POWERGRID

46 Completed by POWERGRID (remaining deficiencies categorically of PLCC at remote end concerned with other utilities).

Some PLCC issues for which POWERGRID (NR-I) is pursuing with UPPTCL. UPPTCL still maintains as per January, 2015 report that PLCC system of Sarnath –Allahabad (PG-2 Nos.), kV Sarnath –Sasaram (PG-1 No), Mau-Balia-PG-I(M-II) and Mau-Balia-PG-II(M-I) lines need to be restored by POWERGRID. POWERGRID reported in the 108th OCC meeting that PLCC at Balia has been restored. In respect of lines from Sarnath, it was intimated that Panels at sarnath belongs to UPPTCL and are to be changed by UPPTCL

16 NTPC 10 June, 2015 Anta, Singrauli, Vindhyachal STPP & 400/220 kV Dadri Sub-station- Completed. 220 kV Dadri Gas & Thermal by March,’15, Tanda, Unchahar & Rihand by June, 2015.

17 NHPC 8 Tanakpur- February, 2015; Chamera-I-March,2015; Chamera-II – June, 2015.

Uri-I, Salal, Chamera-III & Dhauliganga –Completed. NHPC indicated that NEA is being pursued to restore speech channel at Mahendernagar end. NHPC informed in the 28th PCC meeting that spares of GIS for Dulhasti HEP is only left out to be procured and no other deficiencies are left out.

18 SJVNL 1 Feb., 2015 E/F fault in DC System is only left out and expected by Feb., 2015. SJVNL reported in the 108th OCC meeting that that E/F fault in DC System has been rectified on 20.01.2015.

19 THDC 1 Completed. 20 NPCIL 1 March, 2015.

81


Annexure-XI

Status of Third Party Protection Audit (TPPA) of Intra-state transmission system by CPRI and NRPC team of Protection Experts

S.No. Protection Audit by CPRI Utility (s) No. of Sub-Stns./Switchyards

proposed to CPRI Status

1 RRVPNL 220 kV – 39 PA Completed. Report submitted. RRVUNL 400 kV – 5

2 BBMB EHV sub-stn-15 Gen. Stns-4

PA Completed. Report submitted.

3 PSTCL & 220 kV Stns. -22 Report not submitted.

PSPCL 220 kV Switchyards-3 4 UPPTCL 220 kV Stns. (UPPTCL) - 41 Status not known.

UPRVUNL 220 kV Switchyards (UPRVUNL) -3

PA completed. Report not submitted.

5 THDCIL 400 MW Koteshwar HEP Switchyard

PA completed. Report submitted

6 UJVNL Chilla Power House Order to CPRI to be placed. 7 RPL 400 kV Switchyard. Order to CPRI placed. Work is in progress.

S.No.

TPPA by NRPC teams Utility (s) No. of Sub-stns/Switchyards

proposed to NRPC team Status

1 NHPC 220 kV Baira Siul HEP PA Completed. Report submitted.

2 NPCIL 220 kV RAPS-A, B & C PA Completed. Report submitted.

3 HPGCL 220 kV DCRTPP PA Completed. Report submitted.

4 APCLP 400 kV Switchyard PA Completed. Report submitted.

5 JPL, Jhajjar (CLP)

400 kV Switchyard PA not completed

6 DTL 220 kV -25 Out of 25 sub-stns. PA of 4 nos. have been audited.

7 HVPNL 220 kV-5 Out of 5 nos. sub-stns 2 nos. have been audited.

8 HPSEB Ltd. 220 kV -7 Out of 7 nos. sub-stns 2 nos. have been audited.

9 PTCUL 220 kV-4 132 kV -1

Out of 5 nos. sub-stns 2 nos. have been audited.

10 PDD, J&K 220 kV-1 132 kV -2

Order for PA of 2 nos. 132 kV sub-stns have been issued.

11 UT, Chandigarh

220 kV Kishangarh Order for PA issued.

82


Annexure-XII

Details of Generating units expected to be commissioned in 2014-15/2015-16/2016-17

Name of the plant Agency Capacity (in MW) Units Expected Syn.

Actual Syn.

Expected COD

Actual COD

Uhl-III HEP HPSEB Ltd. 33.3 2 Jan., 2015

Uhl-III HEP HPSEB Ltd. 33.3 3 Feb., 2015

Uhl-III HEP HPSEB Ltd. 33.3 1 Mar-15 KALISINDH TPS RRVUNL 660 5 Feb-15 Chhabra TPP Extn RRVUNL 600 2 Suratgarh TPS RRVUNL 660 7 Suratgarh TPS RRVUNL 660 8 Talwandi Sabo Sterlite 660 3 Nov., 2014 Jan., 15

Talwandi Sabo Sterlite 660 2 Oct.2014 Dec., 2014

Baglihar-II JK PDC 150 1 Baglihar-II JK PDC 150 2 Baglihar-II JK PDC 150 3

Lalitpur TPP Lalitpur power Generation Co-op Ltd 660 1


83




Actual Syn.

Expected COD

Actual COD


Kishenganga NHPC 110 1 2016-17 Kishenganga NHPC 110 2 2016-17 Kishenganga NHPC 110 3 2016-17 KOLDAM NTPC 200 1 KOLDAM NTPC 200 2 KOLDAM NTPC 200 3 KOLDAM NTPC 200 4 ANPARA D UPRVUNL 2 500 Dec.-14 Apr-15 BARH-I NTPC 1,2,3 1980 Jun-15 Tapovan Vishnughad

NTPC

1 130 2016-17 Tapovan Vishnughad 2 130 2016-17 Tapovan Vishnughad 3 130 2016-17 Tapovan Vishnughad 4 130 2016-17 Parbati - II (4x200 MW)

NHPC

1 200 2016-17

Parbati - II (4x200 MW) 2 200 2016-17

Parbati - II (4x200 MW) 3 200 2016-17

Parbati - II (4x200 MW) 4 200 2016-17

84




Actual Syn.

Expected COD

Actual COD

Baglihar-II

JK PDC

1 150 2016-17 (3x150 MW) 2 150 2016-17 3 150 2016-17 Kashang-I

HPPCL 1 65 2016-17

(1x65MW) HPPCL Uhl-III

Himachal Pradesh

1 33.33 2016-17 (3x33.33MW) 2 33.33 2016-17 BVPCL (HPSEB) 3 33.33 2016-17 Sawra Kuddu

Himachal Pradesh

1 37 2016-17 (3x37MW) 2 37 2016-17 HPPCL, 3 37 2016-17 Sainj

Himachal Pradesh

1 50 2015-16 (2x50MW) 2 50 2015-16 HPPCL 29.12.2010 Tidong-I

Himachal Pradesh 1 50 2016-17

2x50MW 2 50 2016-17 NSL Tidong Tangnu Romai-I Himachal Pradesh 1 22 2016-17

85




Actual Syn.

Expected COD

Actual COD

(2x22 MW) 2 22 2016-17 TRPGPL Sorang

Himachal Pradesh 1 50 2015-16

(2x50 MW), 2 50 2015-16 HSPPL Shrinagar

Uttarakhand

1 82.5 2015-16 (4x82.5 MW) Alaknanda Hydro Power Co. Ltd.

2 82.5 2015-16

3 82.5 2015-16 4 82.5 2015-16 Singoli Bhatwari

Uttarakhand 1 33 2016-17

(3x33MW) 2 33 2016-17 L&T 3 33 2016-17 Phata Byung

Uttarakhand 1 38 2016-17

(2x38 MW) 2 38 2016-17 LANCO F.G Unchahar TPS St-IV NTPC 1 500

Meja STPP JV of NTPC and

UPRVUNL 1 660

Meja STPP JV of NTPC and

UPRVUNL 2 660

86


Annex-XIII

Report of the group constituted by NRPC on the issue of scheduling of URS power

from Indira Gandhi STPS, Jhajjar

1. Background

1.1 The issue of scheduling of URS power from Indira Gandhi STPS Jhajjar (owned by APCPL) to defaulting states was discussed in 29th TCC and 33rd NRPC meetings. It was decided that a group would be constituted which would study the case and submit report to NRPC.

1.2 Accordingly, a group comprising of following members was constituted by Member

Secretary, NRPC vide letter No. NRPC/ Comml/ 209/ RPC (33rd)/2014 dated 16th January, 2015

1. Sh. Ajay Talagaonkar, Superintending Engineer, NRPC 2. Sh. H.K. Chawla, DGM, NRLDC 3. Sh. Anil Nautiyal, AGM, APCPL

2. Deliberations by the Group

2.1 The group met on 21.01.2015 at NRPC, New Delhi. During deliberations, repreventative of, APCPL reiterated their viewpoint. He stated that NRLDC was scheduling power from Indira Gandhi STPS based on the requisition by beneficiaries. The schedules were at times much more than their actual entitlements due to scheduling of URS power (Un Requisitioned Surplus) by the beneficiaries. Since some beneficiaries did not pay their outstanding charges, he requested that allocation of such beneficiaries should be restricted to their entitlements as per MoP allocations based on the advance advice given to NRLDC.

2.2 Superintending Engineer, NRPC stated that there was no regulatory provision

explicitly dealing with URS power. He was of the opinion that Hon’ble Commission’s order dated 11.01.2010 in the petition No 134/2009 is the only guidance available in the matter. The relevant extract of the order is reproduced below:

“11. Therefore, we do not find any justification for amendment to the regulations for the above purpose. Accordingly, we direct that all the generating stations, governed by the Tariff Regulations of the Commission be allowed to change schedule for the unrequisitioned quantum of power from one beneficiary(s) to another beneficiary(s) of the same power station on the requisition by these beneficiaries through the provision provided in the IEGC, i.e. within six time blocks or as per the provisions of the IEGC as amended from time to time. In case the original beneficiary requests back for its share of power, then its schedule and schedule of beneficiary who had availed URS power would be revised in the six time blocks again, or as specified in the IEGC as amended from time to time. These schedule revisions would be treated as re-allocation of power on temporary basis and would not be taken

87


as open access transactions. The tariff would be governed by the terms and conditions of the tariff regulations applicable to the generating stations.”

2.3 Representative of NRLDC opined that intent of para 11 of the above mentioned

Commission’s order may be taken as onus of changing schedule from one beneficiary to another lies on the generating station. Therefore, request for scheduling of power surrendered by one beneficiary to another beneficiary, who is willing to utilize this power should come from generating station. He also added that a petition regarding URS from Sasan UMPP is under consideration of the Hon’ble Commission and order in the case may also have impact of the process of URS scheduling

2.4 Representative of NRLDC also pointed out that the process of punching of request

by beneficiary for utilizing URS power, and subsequently its consent by the generating station may be taken care of in the scheduling software.

2.5 Superintending Engineer, NRPC expressed that the process of URS scheduling

requires wider deliberations involving generating companies and beneficiaries. Therefore, the issue need to be deliberated in the Commercial sub-committee meeting and TCC/NRPC. This was agreed to by Representative of NRLDC.

2.6 After detailed deliberations, the group finlazed its recommendations as given in the

following section. 3. Recommendations

3.1 NRLDC will continue the present practice of URS Scheduling i.e to Schedule the

URS Power based upon the requisitions received from beneficiaries. However, as a special case, request from APCPL to NRLDC regarding URS power scheduling would be taken care of while scheduling URS power till 31st March, 2015.

3.2 Further action beyond 31st March, 2015 shall be based on uniform procedure

finalized after deliberations in Commercial sub-committee meeting and TCC/NRPC meetings.

Sd/ Sd/ Sd/ (H.K. Chawla) (Anil Nautiyal) (Ajay Talegaonkar)

DGM, NRLDC AGM, APCPL S. E., NRPC

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