spec. no. tata consulting engineers limited section: a …€¦ · tata consulting engineers...

SPEC. NO. TCE.6079B-B-Z-204

TATA CONSULTING ENGINEERS LIMITED SECTION: A

SCOPE OF WORK SHEET 1 OF 4

ISSUE R0

TCE FORM 329 R5 FILE NAME: Islanding & Load shedding spec_R0.doc

1.0 SCOPE OF WORK 1.1. This enquiry covers supply, Installation, Testing and Commissioning of

Dynamic contingency based Islanding & Load shedding System on Lump Sum Turn Key (LSTK) basis at Bharat Petroleum Corporation Limited (BPCL) Mumbai Refinery, to improve the stability of power system. The design basis for the islanding and load shedding schemes is as detailed in Section-C1 of this enquiry document. The detailed specification for all the equipment of the proposed system are covered in Section- C2.

The system architecture for Islanding & Load shedding scheme (ISLS), including Import-Export Limiter (IEL) functionality, Sequence Event Recorder(SER) & Energy Management System(EMS) is as indicated in Exhibit-I : TCE-6079B-EL-SK-2002 of this enquiry document.

1.2. This scope includes the design, manufacture, inspection and testing at VENDOR‟s and/or his SUB-VENDOR‟s works, packing, transportation from place of manufacture to site, unloading and storing at site, handling at site, all associated cabling, cable trays, support structures & complete erection, testing, start-up, commissioning and performance testing of the equipment / system at site as specified.

1.3. It is not the intent to specify completely herein, all the details of design and construction of the equipment /system. However, the equipment shall conform in all respects the latest technology prevailing in the international market and shall also conform in all respects to high standards of engineering, design and workmanship and be capable of performing up to the VENDOR's guarantees in a manner acceptable to the PURCHASER/ENGINEER, who will interpret the meaning of specifications and drawings and shall reject any work or material which in his judgement is not in full accordance therewith.

1.4. The extent of supply under this contract includes all items shown in the appropriate sketches/drawings notwithstanding the fact that such items may have been omitted from the specifications or schedules. Similarly, the extent of supply also includes all items mentioned in the specification and/or schedule, notwithstanding the fact that such items may have been omitted in the sketches/drawings.

1.5. All specialised equipment/services necessary for proper erection, commissioning and performance testing of all items covered under this contract shall be arranged by the CONTRACTOR. The cost of the same shall be included in the contract price.

1.6. The Islanding & Load shedding system will broadly consist of: a) Islanding & Load shedding controller b) Input-Output modules (Remote Terminal Units – RTUs) c) Operator console and peripherals like printers, storage devices, etc. d) Communication network e) Transducers f) Islanding Relays & Load shedding relays g) Auxiliary relays, tripping relays.

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h) Field Cables from/to existing switchgear to/from the Input/Output modules (RTUs).

i) Fibre optic cables from Input/Output modules (RTUs) to the Islanding & Load shedding controller.

j) Engineering station for Islanding & load shedding controller programming with suitable software loaded in it.

k) Desk for the operator console & chairs as required. l) Miscellaneous items like control cables, earthing for power equipment,

earthing for computer system, etc. m) Co-ordination with statutory authorities, if required and getting clearance

from them.

1.7. The Bidder shall organize the inspection at his expense by engaging the services of Inspectors from one of the following reputed third party CLASSIFIED INSPECTING AGENCIES/SOCIETIES like Lloyds, IRS, BVQI, TUV, PDI, etc. The scope of inspection by inspecting agencies shall cover FAT of vendor‟s system; FAT of sub vendor supplied major components, SAT, etc. Along with the third party, the equipment/materials will be inspected and testing witnessed by the PURCHASERs and their representatives. The supplier shall give at least one month‟s notice for readiness of equipment for testing at the manufacturer‟s works. Despatch of materials to site shall be effected only after the receipt of the clearance note from inspecting agency and the despatch clearance from Purchaser.

1.8. The Bidder shall impart the required training to the Purchaser‟s Engineers. The training shall include hardware and software aspects and training shall be comprehensive and shall enable the purchaser‟s engineers to run & maintain the system successfully. Vendor shall submit duration and course content of training program for prior approval of Purchaser. Any test equipment to be supplied along with the system shall be made available during training period. The expenses for imparting above training are deemed to be included in the total quoted prices. The schedule for training shall be as below: a) At vendor‟s works / facility for 4 persons for 4 days minimum. b) At BPCL site after commissioning of the system for 10 persons for 3 days

minimum.

1.9. Bidder shall include essential spares required for successful commissioning of the equipment within the quoted price.

1.10. Bidder shall furnish list of essential spares required with unit prices for 3 years of trouble free operation of the system. The prices shall be remain valid upto 3 years from the expiry of guarantee period. Bidder shall guarantee the supply of spares for 10 years from the date of commissioning.

2.0 TECHNICAL INSTRUCTIONS TO BIDDERS

2.1 All the work involved for installing the complete Islanding & load shedding system shall be in the scope of the bidder. This includes all the modifications required to be done in the existing switchgear, mounting of transducers, auxiliary relays, tripping relays, civil works like floor cutout for cable entry, panel erection, cable terminations, etc.

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2.2 The bidder shall assume full responsibility for the detailed design, equipment

selection, erection and commissioning of the system. The installation shall meet the provision of safety codes and safety rules. The necessary drawings shall be approved from owner/consultant.

2.3 The offered system shall have Proven Track Record (PTR) from minimum 2 users for working satisfactorily for at least last 2 years. The bidder is required to show to PURCHASER /CONSULTANT, a similar Dynamic contingency based load shedding scheme which is in satisfactory operation at the time of evaluation of offer. The total time of the load shedding scheme of such a system shall not be more than 200 milliseconds (including 100 milliseconds of Interposing Relay (IPR) operating time and breaker opening time). The Bidder shall accordingly furnish end-user certificates.

2.4 The bidder shall visit site to see the various substations where RTUs are to be

located & New GIS substation area & CPP control room where the Islanding & Load shedding controllers shall be located. The locations of the load shedding controller, I/O racks shall be confirmed based on the environmental conditions, for satisfactory operation of the load shedding system.

2.5 Documents and drawings to be furnished by the bidder with the bid is given

below: a) System configuration with total bill of material. b) For all equipment:

GA drawings

Equipment specification

Descriptive literature

Testing procedure for testing the system for approval by CONSULTANT/PURCHASER.

c) List of software packages with brief description of each. Software package should be standard / proven, which will be offered by contractor.

d) Block logic diagram for the complete islanding & load shedding scheme. e) Preliminary earthing layout f) List of SUB-VENDORS / SUB-CONTRACTOR for the various equipment

covered in this specification and their past experience In the event of any of the sub-vendors furnished by the bidder is not acceptable to BPCL/Consultant, in such circumstances the bidder shall produce a fresh list of sub-vendors to enable approval by BPCL/Consultant.

Bidder will furnish the list of drawings which require approval by CONSULTANT/PURCHASER.

2.6 IMPLEMENTATION SCHEDULE

2.6.1 The inputs and outputs for the proposed Islanding & Load Shedding System corresponds to plant and equipment which are required to be continuously running. Modifications, wiring, cable glanding, terminating, etc in existing switchgear has to be done by Vendor when the switchgear is taken for outage during scheduled maintenance of the plant.

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2.6.2 Vendor shall indicate the terms and conditions, total time required and implementation schedule in the form of detailed bar-chart.

2.6.3 Vendor shall submit detailed project bar chart showing milestones, covering all the activities till the commissioning of the entire system.

2.7 SYSTEM SUPPORT

The load shedding system offered shall be supported by the supplier for a minimum period of 15 years from the date of commissioning.

2.8 LONG TERM MAINTENANCE FACILITIES

After expiry of warranty period of the equipment, PURCHASER would like to place maintenance contract ( to be renewed annually) for the Load Shedding System, with the CONTRACTOR. The BIDDER shall enclose in the bid a detailed write up on Long Term Maintenance Plan of the equipment giving details of maintenance facilities/back-up available in India. The BIDDER shall also furnish price for 5 years long term maintenance after warranty period with price indicated for each year separately. Getting into agreement for execution of AMC contract shall be at PURCHASER’s discretion.

2.9 WARRANTY

18 months from the date of supply and 12 months from the date of commissioning whichever is earlier.

2.10 Vendor shall provide per man day rate for carrying out modifications required

in the system during one year after commissioning of the system. 15 man days shall be considered for this purpose.

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TATA CONSULTING ENGINEERS LIMITED SECTION: C1

DESIGN BASIS FOR THE SCHEME SHEET 1 OF 64

ISSUE R0


DESIGN BASIS FOR ISLANDING & LOAD SHEDDING SCHEME FOR BPCL MUMBAI REFINERY POWER SYSTEM AFTER ADDITION OF THIRD

TATA FEEDER AND CCR PLANT LOADS

1. INTRODUCTION Dynamic contingency based islanding and load shedding scheme is proposed for BPCL, Mumbai Refinery. The scheme is detailed in this report. The electrical network of BPCL is as indicated in figure below:

Total Generation Capacity = 66MW (GTG1=19, GTG2=19 & GTG3=28) (considering harsh conditions)

Total TPC capacity = 82.8MW (TPC1, 2 & 3 = 27.6MW each, [email protected])

Total Refinery load = 96MW (MRS1=18MW, LBSS=14.5MW, RMP=26.5MW, CCR=24MW, MRS2=13MW)

Normal operating configuration for GTGs operating in parallel with TPC grid shall be as below:

o New & Old GIS Bus-1 shall be Generator bus o New & Old GIS Bus-2 shall be TPC grid bus o New GIS COBT 1 or 2 shall be closed. Old GIS COBT shall be open. o New GIS to Old GIS tie on Bus-2, MRS2 on New GIS Bus-2, LBSS

on old GIS Bus-2 o CCR on New GIS Bus-1, RMP on Old GIS Bus-1, MRS3 to Old GIS

tie on Bus-1, New GIS to MRS3 tie on Bus-1. o New & Old GIS B/Cs closed.

When GTGs are to be operated in isolation from TPC grid, then New GIS COBT 1 & 2 shall be opened. In this case TPCL shall feed MRS2 & LBSS; GTGs shall feed CCR, RMP & MRS1.

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Priority for load shedding is as below:

PRIORITY FOR SHEDDING

SUBSTATION PLANT DETAILS kV VOLTAGE

MW LOAD

1 MRS2 SWH-5 (MMBPL, P/H-5, P/H-4, CPPL, LPG)

6.6 4.8

2 MRS2 MRS2 balance ( DM PLANT, SHOP/ADMN/CDU)

6.6 13 – 4.8 = 8.2

3 LBSS HCP 6.6 2.1

4 LBSS ARU 6.6 3.3

5 LBSS HVU 6.6 1.1

6 LBSS CRU/NSU/HDS/TDU/Pump house-6

6.6 1.8

7 LBSS Old Hydrogen at HT/LT motor

6.6 1.0

8 CCR Unit 142 PSA Recycle Compressor

6.6 2.59

9 CCR Unit 142 Tail Gas Export Compressor

6.6 0.36

10 CCR Unit 141B Regeneration Loop Compressor (Main & Standby)

6.6 0.469

11 CCR Unit 141B Regeneration Loop Drier

0.415 0.612

12 CCR Unit 141B Reduction Heater

0.415 0.486

13 CCR Unit 141B Burning Heater

0.415 0.534

14 CCR Unit 141B Oxychlorination Heater

0.415 0.042

15 CCR Unit 141B Calcination Heater

0.415 0.0756

16 CCR Unit 141B Nitrogen Compressor

0.415 0.053

17 RMP CDU/VDU 6.6 7.0

18 RMP BBU 6.6 1.1

19 RMP LOBS 6.6 1.3

1T MRS2 TOTAL PLANT 22 13.0

2T LBSS TOTAL PLANT 22 14.5

3T CCR TOTAL PLANT 22 24.0

4T RMP TOTAL PLANT 22 26.5

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2. OPERATING PHILOSOPHY a. Based on the normal operating configuration of BPCL system in parallel with

TPC grid, following islanding points are considered for the various cases: a) When all the 3 GTGs are running in parallel with TPC feeders, in case of

any grid disturbance which will be sensed by the islanding relays, the islanding point will be new GIS COBT. Opening of this COBT will result in islanding operation. MRS-2 & LBSS loads will be automatically transferred on TPC. GTGs will feed CCR, RMP & MRS1. Further based on the load -generation balance scheme, if there is a deficit of power in GTG island, equivalent load will be shed from respective island. The deficit of power will be calculated based on the power flow through the COBT and actual generation and loads on generators before islanding and the reserve generation available in the island.

b) When GTG1 or 2 and GTG3 are running in parallel with TPC feeders, in case of any grid disturbance which will be sensed by the islanding relays, the islanding point will be New GIS to MRS3 tie. Opening of this tie will result in islanding operation. MRS-2, LBSS & CCR loads will be automatically transferred on TPC. GTGs will feed RMP & MRS1. Further if based on the load -generation balance scheme, if there is a deficit of power in either TPC island or GTG island, equivalent load will be shed from respective island. The deficit of power will be calculated based on the power flow through the tie feeder and actual generation and loads on generators before islanding and the reserve generation available in the island.

c) When GTG1 and GTG2 are running in parallel with TPC feeders, in case of any grid disturbance which will be sensed by the islanding relays, the islanding point will be New GIS to MRS3 tie. Opening of this tie will result in islanding operation. MRS-2, LBSS & CCR loads will be automatically transferred on TPC. RMP part load (about 7 to 7.5MW) will have to be shed and GTG1 and 2 will feed RMP balance & MRS1. Load shedding will be based on the load -generation balance scheme, if there is a deficit of power in either TPC island or GTG island, equivalent load will be shed from respective island. The deficit of power will be calculated based on the power flow through the tie feeder and actual generation and loads on generators before islanding and the reserve generation available in the island. Based on the criticality of the RMP loads which is being shed, BPCL may decide whether to island or stay connected with grid in this case of 2 small GTGs. However, if system is not islanded for grid disturbances, then there are chances that the total refinery load may be affected.

d) When any 1 GTG is running in parallel with TPC feeders, RMP load shall be shifted from Old GIS Bus-1 (GTG bus) to Bus-2 (TPC bus). In case of any grid disturbance which will be sensed by the islanding relays, the islanding point will be New GIS to MRS3 tie. Opening of this tie will result in islanding operation. MRS-2, LBSS, CCR & RMP loads will be automatically transferred on TPC. Single GTG will feed MRS1.

e) In case of tripping of any of the TPC feeder or/and GTG feeder, the deficit of power will be calculated based on the generation lost and the reserve generation available in the running sources. Equivalent load will be shed.

f) In case of any other operating configuration, if the islanding relays operate, then these shall trip HUT secondary CBs and 22kV MRS2, LBSS

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feeders. Thereafter if the frequency relays provided on the Old GIS Bus-1 or Bus-2 operate, then the CCR and RMP loads will be shed in stages based on the priorities assigned to the loads. This frequency based scheme is a back-up to the dynamic contingency based scheme.

g) In case of GTGs operating in isolation from TPC grid, in case of any 2 GTGS tripping out of 3, or any 1 GTG tripping out of 2, hard-wired scheme along with under frequency and df/dt is recommended for tripping the loads, as the df/dt in these cases will be very high and it is required to shed the loads as fast as possible to increase the chances of saving the running GTG and MRS1 loads.

h) In case of RMP or CCR plant shutdown and 3 GTGs operating in parallel with grid, LBSS feeders shall be shifted to GTG bus i.e. LBSS on Old GIS Bus1. Then in case of any grid disturbance which will be sensed by the islanding relays, the islanding point will be New GIS COBT. GTGs will feed MRS-1, LBSS and RMP or CCR (whichever is not under shutdown) loads. TPC will feed MRS-2 loads

i) Keeping the base configuration, in case of RMP or CCR plant shutdown and GTG1 or 2 and GTG3 operating in parallel with grid, then in case of any grid disturbance which will be sensed by the islanding relays, the islanding point will be New GIS COBT. Opening of this COBT will result in islanding operation. MRS-2 & LBSS will be automatically transferred on TPC. GTG1 or 2 and GTG3 will feed MRS1 and CCR or RMP (based on which plant is shutdown)

j) Keeping the base configuration, in case of RMP or CCR plant shutdown and GTG1 and GTG2 operating in parallel with grid, then in case of any grid disturbance which will be sensed by the islanding relays, the islanding point will be New GIS COBT. Opening of this COBT will result in islanding operation. MRS-2 & LBSS will be automatically transferred on TPC. GTG1 and GTG 2 will feed MRS1 and part CCR or RMP (based on which plant is shutdown). CCR or RMP part load shedding is based on load generation based scheme and load priorities.

b. In all the above cases, when islanding takes place at New COBT or New GIS

to MRS3 tie, parallel command shall go for opening of Old GIS COBT (this is to take care of the case if old GIS COBT is closed due to any reason).

c. The dynamic load shedding scheme recommended is based on load-generation balance principle. In case of loss of any of the TPC feeders or GTGs, load equal to the loss of generation shall be shared amongst the running feeders and generators, upto their operating limits and balance load will be shed, thus maintaining load-generation balance in the system. The possible contingencies like tripping of one or more TPC feeders or GTGs, which can occur in the network, are predefined. For each predefined contingency, the value of loads to be shed will be calculated based on generation MW, load MW & load priorities. Thus, for any contingency, the loads to be shed will be pre-calculated. Now actually when a particular contingency occurs, the load shedding controller will determine the type of contingency and then look into the pre-calculated load to be shed table against that particular contingency and then issue shed commands to the identified loads.

d. Load shedding is not considered for the case when contract demand may get

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exceeded due to loss of internal generation when the system is connected to grid. In such case load shedding is considered in case the grid transformer loading exceeds its capacity.

e. While computing the spinning reserve, the system shall take into account the rate at which the running generators can be ramped up with regard to their power output considering that the total load shedding shall be effected in 0.2 seconds (Including 0.1 sec of Interposing Relay (IPR) operating time and breaker opening time).

f. When islanding takes place or for any reason all TPC feeders trip, command shall go to take out the GTGs from pre-select mode.

g. The actual load shed shall be generally 10% more than the quantum of deficiency.

h. Remote closing of the tripped load breakers shall be included in the scheme. Local/Remote selector switch position shall be monitored for close permissive.

i. The trip command from the PLC shall reset after checking the breaker / contactor feedback. Provision of manual resetting, which will reset all trip commands, shall also be made.

3. INPUTS REQUIRED

The inputs required for the scheme are as follows:-

a. Analogue inputs - Monitor MW power flow in following feeders:

(a) GTG-1 incomer (22kV MRS3)

(b) GTG-2 incomer (22kV MRS3)

(c) GTG-3 incomer (22kV Old GIS)

(d) TPC1 incomer (22kV New GIS)

(e) TPC2 incomer (22kV New GIS)

(f) TPC3 incomer (22kV New GIS)

(g) New GIS COBT1 & 2 (direction of power flow is also to be monitored, i.e. from GTG Bus-1 to TPC Bus-2 or vice-versa) (22kV New GIS)

(h) New GIS to MRS-3 tie 1 & 2 (direction of power flow is also to be monitored, i.e. from MRS3 GTG Bus to New GIS Bus -1 or vice versa) (22kV New GIS)

(i) O/G-1 & 2 to MRS-2 (22kV New GIS)

(j) O/G -1 & 2 to CCR (22kV New GIS)

(k) O/G-1 & 2 to LBSS (22kV Old GIS)

(l) O/G -1 & 2 to RMP (22kV Old GIS)

(m) O/G-1 & 2 to SWH/5 (6.6kV MRS2)

(n) O/G-1 & 2 to HCP (6.6kV LBSS)

(o) O/G-1 & 2 to ARU (6.6kV LBSS)

(p) O/G-1 & 2 to HVU (6.6kV LBSS)

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(q) O/G-1 & 2 to CRU/NSU/HDS/TDU/Pump house-6 (6.6kV LBSS)

(r) O/G to CDU/VDU (6.6kV RMP)

(s) O/G to BBU (6.6kV RMP)

(t) O/G to LOBS (6.6kV RMP)

MW transducers are required for above analog inputs in the respective switchgears. If transducers are not existing, then new transducers are to be installed.

For following motor feeders, MW power shall be calculated as 0.9*motor rating (breaker/contactor feedback shall be taken for determining which motors are running & to be considered for load shedding):

(u) O/G to Old Hydrogen HT/LT motors (6.6kV/415V LBSS)

(v) O/G to Unit 142 PSA Recycle Compressor (6.6kV CCR)

(w) O/G to Unit 142 Tail Gas Export Compressor (6.6kV CCR)

(x) O/G to Unit 141B Regeneration Loop Compressor (Main & Standby) (6.6kV CCR)

(y) O/G to Unit 141B Regeneration Loop Drier (415V CCR)

(z) O/G to Unit 141B Reduction Heater (415V CCR)

(aa) O/G to Unit 141B Burning Heater (415V CCR)

(bb) O/G to Unit 141B Oxychlorination Heater (415V CCR)

(cc) O/G to Unit 141B Calcination Heater (415V CCR)

(dd) O/G to Unit 141B Nitrogen Compressor (415V CCR)

b. Digital inputs: Monitor the status of the following breakers and their isolators

(a) GTG-1 incomer (22kV MRS3)

(b) GTG-2 incomer (22kV MRS3)

(c) GTG-3 incomer (22kV Old GIS)

(d) TPC1 incomer (22kV New GIS)

(e) TPC2 incomer (22kV New GIS)

(f) TPC3 incomer (22kV New GIS)

(g) New GIS COBT1 & 2 (22kV New GIS)

(h) New GIS to MRS-3 tie 1 & 2 (22kV New GIS & MRS3)

(i) O/G-1 & 2 to MRS-2 (22kV New GIS)

(j) O/G -1 & 2 to CCR (22kV New GIS)

(k) O/G-1 & 2 to LBSS (22kV Old GIS)

(l) O/G -1 & 2 to RMP (22kV Old GIS)

(m) New GIS to Old GIS tie 1 & 2 (22kV New GIS & Old GIS)

(n) New GIS B/C-1 & 2 (New GIS)

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(o) Old GIS B/C-1 & 2 (Old GIS)

(p) Old GIS COBT (Old GIS)

(q) MRS3 B/C-1 & 2 (MRS3)

(r) Old GIS to MRS3 tie 1 & 2 (Old GIS)

Following digital inputs per breaker are required :

ON in service position, OFF and TRIP

For circuit breakers, 2 contacts (1 NO + 1 NC) will be used for status change monitoring. Auxiliary relays shall be provided for contact multiplication if required.

Breaker/contactor feedback from feeders/motors (HT & LT) those which are considered for load shedding shall also be taken as digital inputs.

c. Islanding relay operation inputs:

(a) Under frequency with time delay

(b) Under frequency with negative rate of change of frequency

(c) Directional Over Current with Under voltage and time delay

(d) Directional Over Current with Under voltage and negative rate of change of voltage

(e) Over frequency with time delay

(f) Over frequency with positive rate of change of frequency

The islanding scheme shall have following protection settings:

(a) Under frequency with time delay : - 48.5Hz+0.3sec

(b) Under frequency with negative rate of change of frequency: - 49.0Hz+1Hz/sec

(c) Directional Over Current with Under voltage and time delay:- 10% (DOC)+85%(U/V)+100msec Td

(d) Directional Over Current with Under voltage and negative rate of change of voltage:- 10% (DOC)+85%(U/V)+11kV/sec (dv/dt)

(e) Over frequency with time delay: - 51.5Hz+2.5sec

(f) Over frequency with positive rate of change of frequency:- 51.0Hz+1Hz/sec

d. Islanding frequency relays shall be connected to TPC-1, 2 & 3 incomer line

PTs on HUT secondary side in 22kV New GIS. Second set of relays shall be connected to TPC-1, 2 & 3 incomer line PTs on HUT primary side for redundancy.

Voltage relays will be connected to TPC-1, 2 & 3 incomer line PTs on HUT primary side. HUT primary side voltage has to be sensed due to the following reason:

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During an earth fault in TPC 22kV or 110kV system, the HUT secondary star side voltage will be much higher than the primary side voltage, due to the transformer impedance and the vector group (delta on primary side). Hence, the secondary side voltage will not reflect the actual fault condition, though the GTGs will be contributing to the fault. Directional over-current relay will be connected to TPC-1, 2 & 3 incomer line CTs on HUT secondary side in 22kV New GIS. HUT secondary side current has to be sensed due to the following reason: In case of any fault in the HUT zone, if the HUT unit protection (differential and instantaneous over-current protection in case of phase fault and restricted earth fault protection in case of earth fault) fails to operate, the islanding over-current relay will pick-up and operate in 100ms time, thus reducing the voltage dip impact on the total refinery. The relays proposed are as below: 1. Voltage & frequency relays connected to TPC-1, 2 & 3 incomer line PTs

on HUT primary side: L&T supplied Microelettrica Scientifica make UFD34 relay Or AREVA make MICOM P141 relay. 2. Frequency relays connected to TPC-1, 2 & 3 incomer line PTs on HUT

secondary side in 22kV New GIS ABB make SPAF340C relay

Or AREVA make MICOM P941 relay.

3. Directional Overcurrent relay connected to TPC-1, 2 & 3 incomer line CTs on HUT secondary side in 22kV New GIS: AREVA make MICOM P127 relay. Or Siemens supplied Argus make 7SR220 relay

All the above islanding relays will be mounted in the New Islanding & Load shedding panel.

e. For the case when GTGs are operating in isolation from grid and feeding

CCR, RMP & MRS1 loads, the load shedding frequency scheme shall have following settings: Stage-1: - 49Hz + 0.8Hz/sec: - Trip CCR Stage-2: - 48.7Hz+0.3sec: - Trip RMP CDU/VDU, BBU Stage-3: - 48.4Hz+0.3sec: - Trip RMP LOBS Stage-4: - 48.1Hz+0.3sec: - Trip RMP balance Stage-5: - 49Hz + 2Hz/sec: - Trip RMP

f. Load Shedding frequency relays (with 5 frequency stages or higher) will be

connected to Old GIS Buses 1 & 2. The relays proposed are as below:

1. ABB make REF541 relays on Old GIS bus- 1A & 2A. 2. AREVA make MICOM P941 relays on Old GIS bus-1B & 2B.

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All the above load shedding relays will be mounted in the New Islanding & Load shedding panel.

g. In the frequency stages, the higher stages will be wired for tripping the breakers of lower stages also. For e.g. if stage-1 U/F operates, then trip CB1. If stage-2 U/F operates, then trip CB1+CB2, even though, in this case stage-1 will also operate and trip CB1. As back-up, stage-2 will also trip CB1.

h. The comprehensive islanding cum load shedding scheme shall be implemented by providing a Main PLC in the Islanding & load shedding panel at New 22kV GIS Substation, Hot stand-by PLC in CPP control Room and RTU‟s at various substations to be connected to the various switchgears through cables to collect analog and digital signals, and to trip the circuit breakers to effect the islanding and load shedding. These RTU‟s shall be soft linked to the Main PLC through redundant fibre optic cables in ring configuration.

i. One no. operator console shall be provided in Station-2 shift Elect Maintenance Officer room & one no. in CPP control room

j. One no. Engineering station shall be located in MRS-4. k. The proposed architecture for the Islanding & Load shedding System is

indicated in Exhibit-I. l. The Input-Output (I/O) List for Islanding & Load Shedding is as indicated in

Table-2 & 3 ahead.

4. SCHEME DESCRIPTION

There will be a load shedding controller (Main PLC), which will perform the following functions.

(a) Scan the analogue and digital inputs from the RTU I/O modules.

(b) Keep updating the following table continuously based on the analogue inputs.

GENERATION DATA

GENERATION MAX GEN POSSIBLE (BY USER) (has to be correctly fed, as this will determine the amount of load to be shed.)

MIN GEN POSSIBLE (BY USER)

ACTUAL GEN (TRANS-DUCER READING) EVERY 2 SEC DATA

RESERVE = MAX-ACTUAL (Calculated value)

GTG1 19.9 -- --

GTG2 19.9 -- --

GTG3 32.0 -- --

TPC1 27.6 -- --

TPC2 27.6 -- --

TPC3 27.6 -- --

NEW COBT-1 (BI-

NA -- --

VOL-2. of 123




ISSUE R0



MIN GEN POSSIBLE (BY USER)

ACTUAL GEN (TRANS-DUCER READING) EVERY 2 SEC DATA


DIRECTIONAL)

NEW COBT-2 (BI-DIRECTIONAL)

NA -- --

NEW GIS TO MRS3 TIE (BI-DIRECTIONAL)

NA -- --


NA -- --

LOAD DATA

A. LOAD SHEDDING PRIORITIES FOR GTGs OPERATING IN PARALLEL

WITH TPC GRID (NEW COBT CLOSED & NEW GIS TO MRS-3 TIE

CLOSED)

A1. CONTINGENCY: NEW COBT OPENS, POWER FLOW THROUGH NEW COBT WAS FROM GTG BUS-1 TO TPC BUS-2 LOAD SHED = COBT POWER FLOW - TOTAL TPC RESERVE GENERATION



MW LOAD ( ACTUAL AS PER TRANSDUCER READING) *


6.6

2 MRS2 MRS2 balance ( DM PLANT, SHOP/ADMN/CDU)

6.6

3 LBSS HCP 6.6

4 LBSS ARU 6.6

5 LBSS HVU 6.6


6.6

VOL-2. of 123




ISSUE R0






6.6

* In case of 2 nos. feeders to the same load, the MW shall be addition of the two.

A2. CONTINGENCY: NEW COBT OPENS, POWER FLOW THROUGH NEW

COBT WAS FROM TPC BUS-2 TO GTG BUS-1 LOAD SHED = COBT POWER FLOW - TOTAL GTG RESERVE GENERATION





6.6


6.6


6.6


0.415


0.415


0.415


0.415


0.415


0.415

17 RMP CDU/VDU 6.6

18 RMP BBU 6.6

19 RMP LOBS 6.6


VOL-2. of 123




ISSUE R0


A3. CONTINGENCY: NEW GIS TO MRS3 TIES OPEN, POWER FLOW

THROUGH NEW GIS TO MRS3 TIES WAS FROM MRS3 TO NEW GIS LOAD SHED = NEW GIS TO MRS3 TIES POWER FLOW - TOTAL TPC RESERVE GENERATION





6.6

2 MRS2 MRS2 balance (DM PLANT, SHOP/ADMN/CDU)

6.6

3 LBSS HCP 6.6

4 LBSS ARU 6.6

5 LBSS HVU 6.6


6.6


6.6


6.6


6.6


6.6


0.415


0.415


0.415


0.415


0.415


0.415


VOL-2. of 123




ISSUE R0


A4. CONTINGENCY: NEW GIS TO MRS3 TIES OPEN, POWER FLOW

THROUGH NEW GIS TO MRS3 TIES WAS FROM NEW GIS TO MRS3 LOAD SHED = NEW GIS TO MRS3 TIE POWER FLOW - TOTAL GTG RESERVE GENERATION




17 RMP CDU/VDU 6.6

18 RMP BBU 6.6

19 RMP LOBS 6.6


A5. CONTINGENCY ANY TPC OR GTG CB OPENS: LOAD SHED = GENERATION LOST -TOTAL RESERVE GEN (TPC+GTG)





6.6

2 MRS2 MRS2 balance (DM PLANT, SHOP/ADMN/CDU)

6.6

3 LBSS HCP 6.6

4 LBSS ARU 6.6

5 LBSS HVU 6.6


6.6


6.6


6.6


6.6


6.6

11 CCR Unit 141B 0.415

VOL-2. of 123




ISSUE R0





Regeneration Loop Drier


0.415


0.415


0.415


0.415


0.415

17 RMP CDU/VDU 6.6

18 RMP BBU 6.6

19 RMP LOBS 6.6


A6. CONTINGENCY TWO OR MORE TPC OR GTG CBs OPEN:

LOAD SHED = GENERATION LOST -TOTAL RESERVE GEN (TPC+GTG)




1T MRS2 TOTAL PLANT 22

2T LBSS TOTAL PLANT 22

3T CCR TOTAL PLANT 22

4T RMP TOTAL PLANT 22


B LOAD SHEDDING PRIORITIES FOR GTG1+2+3 OPERATING IN

ISOLATION FROM TPC GRID (NEW COBT OPEN & MRS-2 & LBSS ON

TPC)

B1 CONTINGENCY: GTG3 OPENS

LOAD SHED = GTG GENERATION LOST - TOTAL GTG RESERVE GEN

VOL-2. of 123




ISSUE R0





3T CCR TOTAL 22

17 RMP CDU/VDU 6.6

18 RMP BBU 6.6

19 RMP LOBS 6.6


B2 CONTINGENCY: GTG1+2 OR GTG1+ 3 OR GTG2+3 OPEN





3T CCR TOTAL 22

4T RMP TOTAL 22


C LOAD SHEDDING PRIORITIES FOR GTG1+2 OR GTG1+3 OR GTG2+3

OPERATING IN ISOLATION FROM TPC GRID (NEW GIS TO MRS3 TIE

OPEN & MRS-2, LBSS & CCR ON TPC)

C1 CONTINGENCY: ANY GTG CB OPENS LOAD SHED = GTG GENERATION LOST - TOTAL GTG RESERVE GEN




4T RMP TOTAL 22


C2 CONTINGENCY: 2 TPC TRIPS OUT OF 3 OR 1 TPC TRIPS OUT OF 2

LOAD SHED = GTG GENERATION LOST - TOTAL TPC RESERVE GEN

VOL-2. of 123




ISSUE R0





1T MRS2 TOTAL 22

2T LBSS TOTAL 22


D LOAD SHEDDING PRIORITIES FOR GTG1 OR 2 OR 3 OPERATING IN

ISOLATION FROM TPC GRID (NEW GIS TO MRS3 TIE OPEN , RMP ON

GIS BUS-2 & MRS-2, LBSS, CCR, RMP ON TPC)

D1 CONTINGENCY: ANY ONE OR TWO TPC TRIP LOAD SHED = GTG GENERATION LOST - TOTAL TPC RESERVE GEN




1T MRS2 TOTAL PLANT 22

2T LBSS TOTAL PLANT 22

3T CCR TOTAL PLANT 22


E LOAD SHEDDING PRIORITIES FOR GTG1+2+3 OPERATING IN

ISOLATION FROM TPC GRID (NEW COBT OPEN , CCR or RMP PLANT

SHUTDOWN)

E1 CONTINGENCY: GTG3 OPENS





1T MRS2 TOTAL 22

2T LBSS TOTAL 22


6.6 IF CCR IS OPERATIONAL (If CCR load is less than 5 MW


6.6

VOL-2. of 123




ISSUE R0






6.6 then CCR plant shall be considered as under shutdown. If load is more than 5 MW, then CCR plant shall be considered as running)


0.415


0.415


0.415


0.415


0.415


0.415

17 RMP CDU/VDU 6.6 IF RMP IS OPERATIONAL (If RMP load is less than 8 MW then RMP plant shall be considered as under shutdown. If load is more than 8 MW, then RMP plant shall be considered as running)

18 RMP BBU 6.6

19 RMP LOBS 6.6


E2 CONTINGENCY: GTG1+2 OR GTG1+ 3 OR GTG2+3 OPEN





VOL-2. of 123




ISSUE R0





1T MRS2 TOTAL 22

2T LBSS TOTAL 22

3T CCR TOTAL 22 IF CCR IS OPERATIONAL (If CCR load is less than 5 MW then CCR plant shall be considered as under shutdown. If load is more than 5 MW, then CCR plant shall be considered as running)

4T RMP TOTAL 22 IF RMP IS OPERATIONAL (If RMP load is less than 8 MW then RMP plant shall be considered as under shutdown. If load is more than 8 MW, then RMP plant shall be considered as running)


(c) There will be an operator console from where the operator will feed in the maximum generating MW limit for GTGs, as and when required. Also, he will feed in the priorities for load shedding, in the above generation & load tables. These entries will be password protected. The priority of any load within a particular plant can be altered; however the priority for the plants shall not be altered. For e.g. the priorities for LOBS and CDU/VDU can be interchanged in RMP, however priority cannot be interchanged between RMP & LBSS or CCR.

VOL-2. of 123




ISSUE R0


(d) The load shedding controller will have the following predefined contingency as given in table-1 below:

VOL-2. of 123




TCE FORM NO. 329 R5

ISSUE R0

Table-1

Dynamic contingency and load-generation balance based Load shedding scheme for

Total refinery load of 96MW (MRS1-18MW, RMP-26.5MW, CCR-24MW, LBSS-14.5MW & MRS2-13MW)

CA

SE NO

.

DESCRIPTION

(Network

determination)

TPC1

MW (Measu

red)

TPC2

MW (Measu

red)

TPC3

MW (Measur

ed)

GTG1

MW (Measur

ed)

GTG2

MW (Measur

ed)

GTG3

MW (Measur

ed)

CONTINGE

NCY (interrupt to

the controller

ISLANDING

POINT(

controller output)

TOTAL GEN

CAPACI

TY (MW) based on

max

generation possible

TOTAL LOAD

ON

GENERATORS

TOTAL

TPC CAPACIT

Y (MW)

TOTAL

LOAD

ON TPC

POWER DEFICIT =

GENERATION

LOSS MW (measured)

SPINNING RESERVE

(Calculated

: Max-Actual)

LOAD

SHEDDING (MW) =

POWER

DEFICIT – SPINNING

RESERVE

LOAD

SHED

TABLE (as per

load MW

measured)

1

TPC1+2+

3 IN PARALL

EL WITH

GTG1+2+3

10 10 10 19 19 28

Grid

disturbance

(islanding

relays

operated)

NEW

COBT 66

MRS1+RMP+

CCR=

68.5

82.8

MRS2+

LBSS=2

7.5

Power flow

through COBT

= -2.5 (from

TPC bus to

GTG bus)

0 in GTG

island

2.5 in GTG

island A2

2 GTG3 trips - 38 38 82.8 58 GTG3 gen =28

82.8-30 = 52.8 in

TPC

feeders

NO A5

3 GTG1 or 2

trips - 47 47 82.8 49 GTG1 gen = 19

82.8-30 =

52.8 in

TPC feeders

NO A5

4 GTG1 or 2

+3 trip - 19 19 82.8 77

GTG1 + 3 gen

= 47

82.8-30 =

52.8 in

TPC

feeders

NO A5

5 GTG1 + 2

trip - 28 28 82.8 68

GTG1 + 2 gen = 38

82.8-30 =

52.8 in TPC

feeders

NO A5

6 GTG1 +2 +

3 trip - 0 0 82.8 96

GTG1 + 2 + 3 gen = 66

82.8-30 =

52.8 in TPC

feeders

66-52.8 = 13.2

A5

VOL-2. of 123




TCE FORM NO. 329 R5

ISSUE R0

CA

SE NO

.

DESCRIPTION

(Network

determina

tion)

TPC1

MW (Measu

red)

TPC2

MW (Measu

red)

TPC3

MW (Measur

ed)

GTG1

MW (Measur

ed)

GTG2

MW (Measur

ed)

GTG3

MW (Measur

ed)

CONTINGE

NCY (interrupt to

the controller

ISLANDING

POINT(

controlle

r output)

TOTAL GEN

CAPACI

TY (MW) based on

max

generation possible

TOTAL LOAD

ON

GENER

ATORS

TOTAL

TPC CAPACIT

Y (MW)

TOTAL

LOAD

ON TPC

POWER DEFICIT =

GENERATION

LOSS MW

(measured)

SPINNING RESERVE

(Calculated

: Max-

Actual)

LOAD

SHEDDING (MW) =

POWER

DEFICIT –

SPINNING

RESERVE

LOAD

SHED

TABLE (as per

load MW

measured)

7 GTG1 or 2 + TPC-1 or 2

or 3trip

- 47 47 55.2 49 GTG1 + TPC-1

= 29

55.2-20 =

35.2 in

TPC feeders

NO A5

8 TPC-1or 2 or

3 trips - 66 66 55.2 30 TPC1 = 10

55.2-20 =

35.2 in

TPC feeders

NO A5

9 TPC-1 + 2 or 2 + 3 or 1 +3

trip

- 66 66 27.6 30 TPC1+2 = 20

27.6-10 =

17.6 in

TPC feeders

20-17.6 =

2.4 A5

10 TPC-1 + 2 +

3 trip - 66 66 0 30

TPC1+2+3 =

30 0 30 A5

11

TPC1+2

IN

PARALL

EL WITH

GTG1+2+3

(TPC3 OUT)

Similar

15 15 - 19 19 28

Grid

disturbance(islanding

relays

operated)

NEW

COBT 66

MRS1+

RMP+

CCR=68.5

55.2 MRS2+LBSS=2

7.5

Power flow

through COBT = -2.5 (from

TPC bus to

GTG bus)

0 in GTG

island

2.5 in GTG

island A2

12 GTG3 trips - 38 38 55.2 58 GTG3gen =28

55.2-30 =

25.2 in

TPC feeders

28-25.2

=2.8 A5

VOL-2. of 123




TCE FORM NO. 329 R5

ISSUE R0

CA

SE NO

.

DESCRIPTION

(Network

determina

tion)

TPC1

MW (Measu

red)

TPC2

MW (Measu

red)

TPC3

MW (Measur

ed)

GTG1

MW (Measur

ed)

GTG2

MW (Measur

ed)

GTG3

MW (Measur

ed)

CONTINGE

NCY (interrupt to

the controller

ISLANDING

POINT(

controlle

r output)

TOTAL GEN

CAPACI

TY (MW) based on

max

generation possible

TOTAL LOAD

ON

GENER

ATORS

TOTAL

TPC CAPACIT

Y (MW)

TOTAL

LOAD

ON TPC

POWER DEFICIT =

GENERATION

LOSS MW

(measured)

SPINNING RESERVE

(Calculated

: Max-

Actual)

LOAD

SHEDDING (MW) =

POWER

DEFICIT –

SPINNING

RESERVE

LOAD

SHED

TABLE (as per

load MW

measured)

13

cases for

TPC1+3

IN PARALL

EL WITH

GTG1+2+3

(TPC2

OUT)

Similar

cases for TPC2+3

IN PARALL

EL WITH

GTG1+2+3

(TPC1

OUT)

GTG1 or 2

trips - 47 47 55.2 49 GTG1 gen = 19

55.2-30 =

25.2 in

TPC feeders

NO A5

14 GTG1 + 3 or

GTG2 + 3

trip

- 19 19 55.2 77 GTG1 + 3 gen

= 47

55.2-30 =

25.2 in

TPC feeders

47-25.2 =

21.8 A5

15 GTG1 + 2

trip - 28 28 55.2 68

GTG1 + 2 gen

= 38

55.2-30 =

25.2 in

TPC feeders

38-25.2 =

12.8 A5

16 GTG1 + 2

+3 trip - - - 55.2 96

GTG1 + 2 +3

gen = 66

55.2-30 =

25.2 in

TPC feeders

66-25.2 =

40.8 A6

17 TPC-2 or 3

trips - 66 66 27.6 30 TPC-2 = 15

27.6-15 =

12.6 in

TPC feeders

15-12.6 =

2.4 A5

18 TPC-2 + 3

trip - 66 66 0 30 TPC-2+3 = 30 0 30 A5

VOL-2. of 123




TCE FORM NO. 329 R5

ISSUE R0

CA

SE NO

.

DESCRIPTION

(Network

determina

tion)

TPC1

MW (Measu

red)

TPC2

MW (Measu

red)

TPC3

MW (Measur

ed)

GTG1

MW (Measur

ed)

GTG2

MW (Measur

ed)

GTG3

MW (Measur

ed)

CONTINGE

NCY (interrupt to

the controller

ISLANDING

POINT(

controlle

r output)

TOTAL GEN

CAPACI

TY (MW) based on

max

generation possible

TOTAL LOAD

ON

GENER

ATORS

TOTAL

TPC CAPACIT

Y (MW)

TOTAL

LOAD

ON TPC

POWER DEFICIT =

GENERATION

LOSS MW

(measured)

SPINNING RESERVE

(Calculated

: Max-

Actual)

LOAD

SHEDDING (MW) =

POWER

DEFICIT –

SPINNING

RESERVE

LOAD

SHED

TABLE (as per

load MW

measured)

19 TPC1 IN

PARALLEL WITH

GTG1+2+

3 (TPC2+3

OUT)

Similar

cases for

TPC2 IN PARALL

EL WITH

GTG1+2+3

(TPC1+3

OUT)

Similar

cases for TPC3 IN

PARALL

EL WITH GTG1+2+

3

(TPC1+2 OUT)

- - 27.6 19 19 28

Grid


relays

operated)

NEW

COBT 66

MRS1+

RMP+

CCR=68.5

27.6

MRS2+

LBSS=

25.1 (2.4MW

load has

been shed)

Power flow

through COBT = -2.5 (from

TPC bus to

GTG bus)

0 in GTG

island

2.5 in GTG

island A2

20 GTG3 trips - 38 38 27.6 55.6 GTG3gen =28 0 28 A5

21 GTG1 trips - 47 47 27.6 46.6 GTG1 gen = 19 0 19 A5

22 GTG1 or 2 +

GTG3 trip - 19 19 27.6 74.6

GTG1 + 3 gen = 47

0 47 A6

23 GTG1 + 2

trip - 28 28 27.6 65.6

GTG1 + 2 gen = 38

0 38 A6

24 GTG1 + 2

+3 trip - - - 27.6 93.6

GTG1 + 2 +3 gen = 66

0 66 A6

VOL-2. of 123




TCE FORM NO. 329 R5

ISSUE R0

CA

SE NO

.

DESCRIPTION

(Network

determina

tion)

TPC1

MW (Measu

red)

TPC2

MW (Measu

red)

TPC3

MW (Measur

ed)

GTG1

MW (Measur

ed)

GTG2

MW (Measur

ed)

GTG3

MW (Measur

ed)

CONTINGE

NCY (interrupt to

the controller

ISLANDING

POINT(

controlle

r output)

TOTAL GEN

CAPACI

TY (MW) based on

max

generation possible

TOTAL LOAD

ON

GENER

ATORS

TOTAL

TPC CAPACIT

Y (MW)

TOTAL

LOAD

ON TPC

POWER DEFICIT =

GENERATION

LOSS MW

(measured)

SPINNING RESERVE

(Calculated

: Max-

Actual)

LOAD

SHEDDING (MW) =

POWER

DEFICIT –

SPINNING

RESERVE

LOAD

SHED

TABLE (as per

load MW

measured)

25 TPC 3 trip - 66 66 0 27.6 TPC-3 = 27.6 0 27.6 A5

26

TPC1+2+

3 IN

PARALLEL WITH

GTG1+2

(GTG3 OUT)

19.33 19.33 19.33 19 19 -

Grid

disturbance(i

slanding relays

operated)

New GIS to

MRS3

tie

38

MRS1+

RMP = 44.5

82.8

MRS2+LBSS+C

CR =

51.5

Power flow through New

GIS to MRS3

tie = 6.5MW

0 in GTG

island 6.5-0 = 6.5 A4

27 GTG1 or 2

trips - 19 19 82.8 77 GTG1 gen = 19

82.8-57.99 = 24.81 in

TPC

feeders

NO A5

28 GTG1 + 2

trip - - - 82.8 96

GTG1+2 gen =

38

82.8-57.99 = 24.81 in

TPC feeders

38-24.81 =

13.2 A5

29 TPC-1 or 2

or 3 trips - 38 38 55.2 58 TPC1 = 19.33

55.2-

38.66=

16.54 in TPC

feeders

19.33-16.54

= 2.8 A5

30

TPC-1 + 2 or

2 + 3 or 1 +3 trip

- 38 38 27.6 58 TPC1 + 2=

38.66

27.6-19.33= 8.27

in TPC

feeders

38.66-8.27

= 30.4 A5

31 TPC-1 + 2 +

3 trip - 38 38 0 58

TPC1+ 2+3 = 58

0 58 A6

VOL-2. of 123




TCE FORM NO. 329 R5

ISSUE R0

CA

SE NO

.

DESCRIPTION

(Network

determina

tion)

TPC1

MW (Measu

red)

TPC2

MW (Measu

red)

TPC3

MW (Measur

ed)

GTG1

MW (Measur

ed)

GTG2

MW (Measur

ed)

GTG3

MW (Measur

ed)

CONTINGE

NCY (interrupt to

the controller

ISLANDING

POINT(

controlle

r output)

TOTAL GEN

CAPACI

TY (MW) based on

max

generation possible

TOTAL LOAD

ON

GENER

ATORS

TOTAL

TPC CAPACIT

Y (MW)

TOTAL

LOAD

ON TPC

POWER DEFICIT =

GENERATION

LOSS MW

(measured)

SPINNING RESERVE

(Calculated

: Max-

Actual)

LOAD

SHEDDING (MW) =

POWER

DEFICIT –

SPINNING

RESERVE

LOAD

SHED

TABLE (as per

load MW

measured)

32

TPC1+2+

3 IN PARALL

EL WITH

GTG1+3 (GTG2

OUT)

Similar cases for

TPC1+2+

3 IN PARALL

EL WITH

GTG2+3 (GTG1

OUT)

16.33 16.33 16.33 19. - 28

Grid


relays

operated)

New

GIS to

MRS3 tie

47 MRS1+RMP =

44.5

82.8

MRS2+

LBSS+C

CR = 51.5

Power flow

through New

GIS to MRS3 tie = -3MW

0 in GTG

island NO -

33 GTG1 trips - 28 28 82.8 68 GTG1 gen = 19

82.8-48.99

= 33.81 in

TPC feeders

NO A5

34 GTG3 trips - 19 19 82.8 77 GTG3 gen = 28

82.8-48.99

= 33.81 in

TPC feeders

NO A5

35 GTG 1+ 3

trip - - - 82.8 96

GTG 1 + 3 gen

= 47

82.8-48.99

= 33.81 in

TPC feeders

47-33.81

=13.2 A5

36 TPC-1 trips - 47 47 55.2 49 TPC1 = 16.33

55.2-

32.66= 22..54 in

TPC

feeders

NO A5

37 TPC-1 + 2 or 2 + 3 or 1 +

3 trip

- 47 47 27.6 49 TPC1 + 2=

32.66

27.6-

16.33= 11.27 in

TPC

feeders

32.66-11.27

= 21.4 A5

VOL-2. of 123




TCE FORM NO. 329 R5

ISSUE R0

CA

SE NO

.

DESCRIPTION

(Network

determina

tion)

TPC1

MW (Measu

red)

TPC2

MW (Measu

red)

TPC3

MW (Measur

ed)

GTG1

MW (Measur

ed)

GTG2

MW (Measur

ed)

GTG3

MW (Measur

ed)

CONTINGE

NCY (interrupt to

the controller

ISLANDING

POINT(

controlle

r output)

TOTAL GEN

CAPACI

TY (MW) based on

max

generation possible

TOTAL LOAD

ON

GENER

ATORS

TOTAL

TPC CAPACIT

Y (MW)

TOTAL

LOAD

ON TPC

POWER DEFICIT =

GENERATION

LOSS MW

(measured)

SPINNING RESERVE

(Calculated

: Max-

Actual)

LOAD

SHEDDING (MW) =

POWER

DEFICIT –

SPINNING

RESERVE

LOAD

SHED

TABLE (as per

load MW

measured)

38 TPC-1 + 2 +

3 trip - 47 47 0 49

TPC1+ 2+3

=49 0 49 A6

39 TPC1+2

IN

PARALLEL WITH

GTG1+2

(GTG3 & TPC3

OUT)

Similar

cases for

TPC1+3 IN

PARALLEL WITH

GTG1+2

(GTG3 & TPC2

OUT)

Similar

cases for

TPC2+3

27.6 27.6 - 19 19 - Grid

disturbance(i

slanding relays

operated)

New GIS to

MRS3

tie

38 MRS1+

RMP

=44.5

55.2 MRS2+

LBSS+

CCR =48.7

(2.8MW

of MRS2 has been

shed)

Power flow

through New

GIS to MRS3 tie = 6.5

0 in GTG

island

6.5 in GTG

island

A4

40 GTG1 or 2 trips

- 19 19 55.2 74.2 GTG1 gen = 19 0 19 A5

41 GTG1 + 2 trip

- 0 0 55.2 93.2 GTG1 + 2 gen = 38

0 38 A6

42 TPC-1 or 2 trips

- 38 38 27.6 55.2 TPC-2 = 27.6 0 27.6 A5

VOL-2. of 123




TCE FORM NO. 329 R5

ISSUE R0

CA

SE NO

.

DESCRIPTION

(Network

determina

tion)

TPC1

MW (Measu

red)

TPC2

MW (Measu

red)

TPC3

MW (Measur

ed)

GTG1

MW (Measur

ed)

GTG2

MW (Measur

ed)

GTG3

MW (Measur

ed)

CONTINGE

NCY (interrupt to

the controller

ISLANDING

POINT(

controlle

r output)

TOTAL GEN

CAPACI

TY (MW) based on

max

generation possible

TOTAL LOAD

ON

GENER

ATORS

TOTAL

TPC CAPACIT

Y (MW)

TOTAL

LOAD

ON TPC

POWER DEFICIT =

GENERATION

LOSS MW

(measured)

SPINNING RESERVE

(Calculated

: Max-

Actual)

LOAD

SHEDDING (MW) =

POWER

DEFICIT –

SPINNING

RESERVE

LOAD

SHED

TABLE (as per

load MW

measured)

43 IN

PARALL

EL WITH GTG1+2

(GTG3 &

TPC1 OUT)

TPC-1 + 2

trip

- 38 38 0 55.2 TPC-1+2 =

55.2

0 55.2 A6

44 TPC1+2

IN PARALL

EL WITH

GTG1+3 (GTG2 &

TPC3

OUT)

Similar

cases for TPC1+3

IN

PARALL

EL WITH

GTG1+3

(GTG2 & TPC2

OUT)

Similar

24.5 24.5 - 19 - 28 Grid


relays

operated)

New

GIS to MRS3

tie

47 MRS1+

RMP =44.5

55.2 MRS2+

LBSS+ CCR=

51.5

Power flow

through New GIS to MRS3

tie = - 2.5

0 in GTG

island

NO -

45 GTG1 or 2

trips

- 28 28 55.2 68 GTG1 gen = 19

55.2-49=

6.2 in TPC

feeders

19-6.2 =

12.85

A5

46 GTG3 trips - 19 19 55.2 77 GTG3 gen =28

55.2-49=

6.2 in TPC

feeders

28-6.2 =

21.8

A5

47 GTG1 + 3

trip

- 0 0 55.2 96 GTG1 + 3 gen

= 47 55.2-49=

6.2 in TPC

feeders

47-6.2=

40.8

A6

VOL-2. of 123




TCE FORM NO. 329 R5

ISSUE R0

CA

SE NO

.

DESCRIPTION

(Network

determina

tion)

TPC1

MW (Measu

red)

TPC2

MW (Measu

red)

TPC3

MW (Measur

ed)

GTG1

MW (Measur

ed)

GTG2

MW (Measur

ed)

GTG3

MW (Measur

ed)

CONTINGE

NCY (interrupt to

the controller

ISLANDING

POINT(

controlle

r output)

TOTAL GEN

CAPACI

TY (MW) based on

max

generation possible

TOTAL LOAD

ON

GENER

ATORS

TOTAL

TPC CAPACIT

Y (MW)

TOTAL

LOAD

ON TPC

POWER DEFICIT =

GENERATION

LOSS MW

(measured)

SPINNING RESERVE

(Calculated

: Max-

Actual)

LOAD

SHEDDING (MW) =

POWER

DEFICIT –

SPINNING

RESERVE

LOAD

SHED

TABLE (as per

load MW

measured)

48 cases for

TPC2+3

IN PARALL

EL WITH

GTG1+3 (GTG2 &

TPC1

OUT)

Similar

case with GTG1 out

instead of GTG2

TPC-1 or 2

trips

- 47 47 0 49 TPC-2 = 24.5 27.6-24.5=

3.1 in TPC

feeders

24.5-3.1 =

21.4

A5

49 TPC-1 + 2

trip

- 47 47 0 49 TPC-1+2 = 49 0 49 A6

50 TPC1 IN

PARALL

EL WITH GTG1+2

(GTG3 &

TPC2+3

OUT)

Similar cases for

TPC2 IN

27.6 - - 19 19 - Grid

disturbance(i

slanding relays

operated)

New

GIS to

MRS3 tie

38 MRS1+

RMP

=44.5

27.6 CCR

=21.1

(30.4MW load

has been

shed)

Power flow

through New

GIS to MRS3 tie = 6.5

0 in GTG

island

6.5 in GTG

island

A4

51 GTG1 or 2

trips

- 19 19 27.6 46.6 GTG1 gen = 19 0 19 A5

VOL-2. of 123




TCE FORM NO. 329 R5

ISSUE R0

CA

SE NO

.

DESCRIPTION

(Network

determina

tion)

TPC1

MW (Measu

red)

TPC2

MW (Measu

red)

TPC3

MW (Measur

ed)

GTG1

MW (Measur

ed)

GTG2

MW (Measur

ed)

GTG3

MW (Measur

ed)

CONTINGE

NCY (interrupt to

the controller

ISLANDING

POINT(

controlle

r output)

TOTAL GEN

CAPACI

TY (MW) based on

max

generation possible

TOTAL LOAD

ON

GENER

ATORS

TOTAL

TPC CAPACIT

Y (MW)

TOTAL

LOAD

ON TPC

POWER DEFICIT =

GENERATION

LOSS MW

(measured)

SPINNING RESERVE

(Calculated

: Max-

Actual)

LOAD

SHEDDING (MW) =

POWER

DEFICIT –

SPINNING

RESERVE

LOAD

SHED

TABLE (as per

load MW

measured)

52 PARALL

EL WITH

GTG1+2 (GTG3 &

TPC1+3

OUT)

Similar

cases for TPC3 IN

PARALL

EL WITH GTG1+2

(GTG3 & TPC1+2

OUT)

GTG1 + 2

trip

- 0 0 27.6 65.6 GTG1 + 2 gen

= 38

0 38 A6

53 TPC-1 trips - 38 38 0 27.6 TPC-1 = 27.6 0 27.6 A5

54 TPC1 IN

PARALLEL WITH

GTG1+3

(GTG2 & TPC2+3

OUT)

Similar

cases for

TPC2 IN PARALL

27.6 - - 19 - 28 Grid


relays

operated)

New

GIS to MRS3

tie

47 MRS1+

RMP =44.5

27.6 LBSS+

CCR =30.1

(21.4M

W load has been

shed)

Power flow


tie = -2.5

0 in GTG

island

2.5 in TPC

island

A3

55 GTG1 trips - 28 28 27.6 46.6 GTG1 gen = 19 0 19 A5

VOL-2. of 123




TCE FORM NO. 329 R5

ISSUE R0

CA

SE NO

.

DESCRIPTION

(Network

determina

tion)

TPC1

MW (Measu

red)

TPC2

MW (Measu

red)

TPC3

MW (Measur

ed)

GTG1

MW (Measur

ed)

GTG2

MW (Measur

ed)

GTG3

MW (Measur

ed)

CONTINGE

NCY (interrupt to

the controller

ISLANDING

POINT(

controlle

r output)

TOTAL GEN

CAPACI

TY (MW) based on

max

generation possible

TOTAL LOAD

ON

GENER

ATORS

TOTAL

TPC CAPACIT

Y (MW)

TOTAL

LOAD

ON TPC

POWER DEFICIT =

GENERATION

LOSS MW

(measured)

SPINNING RESERVE

(Calculated

: Max-

Actual)

LOAD

SHEDDING (MW) =

POWER

DEFICIT –

SPINNING

RESERVE

LOAD

SHED

TABLE (as per

load MW

measured)

56 EL WITH

GTG1+3

(GTG2 & TPC1+3

OUT)

Similar

cases for

TPC3 IN PARALL

EL WITH

GTG1+3 (GTG2 &

TPC1+2 OUT)

Similar cases with

GTG 1

out instead of

GTG2

GTG3 trips - 19 19 27.6 55.6 GTG3 gen = 28 0 28 A5

57 GTG1 + 3

trip

- 0 0 27.6 74.6 GTG1 + 3 gen

= 47

0 47 A6

58 TPC-1 trips - 47 47 0 27.6 TPC-1 = 27.6 0 27.6 A5

59

TPC1+2+

3 IN

PARALL

EL WITH GTG1

(GTG2+3

OUT)

Similar

25.66 25.66 25.66 19. - -

Grid disturbance(i

slanding

relays operated)

New

GIS to MRS3

tie

19 MRS1 =

18 82.8

MRS2+

LBSS+CCR+RM

P = 78

Power flow


tie = -1MW

0 in GTG island

NO -

60 GTG1 trips - 0 0 82.8 96 GTG1 gen = 19

82.8-77 =

5.8 in TPC

feeders

19-5.8= 13.2

A5

VOL-2. of 123




TCE FORM NO. 329 R5

ISSUE R0

CA

SE NO

.

DESCRIPTION

(Network

determina

tion)

TPC1

MW (Measu

red)

TPC2

MW (Measu

red)

TPC3

MW (Measur

ed)

GTG1

MW (Measur

ed)

GTG2

MW (Measur

ed)

GTG3

MW (Measur

ed)

CONTINGE

NCY (interrupt to

the controller

ISLANDING

POINT(

controlle

r output)

TOTAL GEN

CAPACI

TY (MW) based on

max

generation possible

TOTAL LOAD

ON

GENER

ATORS

TOTAL

TPC CAPACIT

Y (MW)

TOTAL

LOAD

ON TPC

POWER DEFICIT =

GENERATION

LOSS MW

(measured)

SPINNING RESERVE

(Calculated

: Max-

Actual)

LOAD

SHEDDING (MW) =

POWER

DEFICIT –

SPINNING

RESERVE

LOAD

SHED

TABLE (as per

load MW

measured)

61

cases for

TPC1+2+

3 IN PARALL

EL WITH

GTG2 (GTG1+3

OUT)

RMP shall

be

connected to GIS

Bus-2

TPC-1 trips - 19 19 55.2 77 TPC1 = 25.66

55.2-

51.32= 3.88

in TPC feeders

25.66-3.88

=21.8 A5

62 TPC-1 + 2 or 2 + 3 or 1 +

3 trip

- 19 19 27.6 77 TPC1 + 2 =

51.32

27.6-

25.66= 1.94

in TPC feeders

51.32-1.94

= 49.4 A6

63 TPC-1 + 2 +

3 trip - 19 19 0 77

TPC1+ 2+3

=77 0 77 A6

64

TPC1+2+3 IN

PARALL

EL WITH GTG3

(GTG1+2

OUT)

RMP shall be

connected

to GIS Bus-2

22.66 22.66 22.66 - - 28

Grid


relays

operated)

New

GIS to

MRS3 tie

28 MRS1 =

18 82.8

MRS2+

LBSS+C

CR+RMP = 78

Power flow

through New

GIS to MRS3 tie = -10MW

0 in GTG

island NO -

65 GTG3 trips - 0 0 82.8 96 GTG3 gen = 28

82.8-68 =

14.8 in

TPC feeders

28-14.8 =

13.2 A5

66 TPC-1 trips - 28 28 55.2 68 TPC1 = 22.66

55.2-

45.32= 9.88

in TPC feeders

22.66-9.88

=12.8 A5

VOL-2. of 123




TCE FORM NO. 329 R5

ISSUE R0

CA

SE NO

.

DESCRIPTION

(Network

determina

tion)

TPC1

MW (Measu

red)

TPC2

MW (Measu

red)

TPC3

MW (Measur

ed)

GTG1

MW (Measur

ed)

GTG2

MW (Measur

ed)

GTG3

MW (Measur

ed)

CONTINGE

NCY (interrupt to

the controller

ISLANDING

POINT(

controlle

r output)

TOTAL GEN

CAPACI

TY (MW) based on

max

generation possible

TOTAL LOAD

ON

GENER

ATORS

TOTAL

TPC CAPACIT

Y (MW)

TOTAL

LOAD

ON TPC

POWER DEFICIT =

GENERATION

LOSS MW

(measured)

SPINNING RESERVE

(Calculated

: Max-

Actual)

LOAD

SHEDDING (MW) =

POWER

DEFICIT –

SPINNING

RESERVE

LOAD

SHED

TABLE (as per

load MW

measured)

67 TPC-1 + 2 or 2 + 3 or 1 +

3 trip

- 28 28 27.6 68 TPC1 + 2 =

45.32

27.6-22.66 =5 in TPC

feeders

45.3-5 =

40.3 A6

68 TPC-1 + 2 +

3 trip - 28 28 0 68

TPC1+ 2+3

=68 0 68 A6

69 GTG1+2+

3

(NEW COBT

OPEN)

- - - 19 19 28 GTG3 trips - 38 38 - - GTG3gen =28 0 28 B1

70 GTG1 or 2

trips

- 47 47 - - GTG1 gen = 19 0 19 B1

71 GTG1 or 2 +

GTG3 trip

- 19 19 - - GTG1 + 3 gen

= 47

0 47# B2

72 GTG1 + 2

trip

- 28 28 - - GTG1 + 2 gen

= 38

0 38 # B2

VOL-2. of 123




TCE FORM NO. 329 R5

ISSUE R0

CA

SE NO

.

DESCRIPTION

(Network

determina

tion)

TPC1

MW (Measu

red)

TPC2

MW (Measu

red)

TPC3

MW (Measur

ed)

GTG1

MW (Measur

ed)

GTG2

MW (Measur

ed)

GTG3

MW (Measur

ed)

CONTINGE

NCY (interrupt to

the controller

ISLANDING

POINT(

controlle

r output)

TOTAL GEN

CAPACI

TY (MW) based on

max

generation possible

TOTAL LOAD

ON

GENER

ATORS

TOTAL

TPC CAPACIT

Y (MW)

TOTAL

LOAD

ON TPC

POWER DEFICIT =

GENERATION

LOSS MW

(measured)

SPINNING RESERVE

(Calculated

: Max-

Actual)

LOAD

SHEDDING (MW) =

POWER

DEFICIT –

SPINNING

RESERVE

LOAD

SHED

TABLE (as per

load MW

measured)

73 GTG1+2

(GTG3

OUT) (NEW

COBT

OPEN)

- - - 19 19 - GTG1 trips - 19 19 - - GTG2gen =19 0 19# C1

74 GTG2 trips - 19 19 - - GTG1 gen = 19 0 19# C1

75 GTG1 or

2 + 3

(GTG2 or 1 OUT )

(NEW

COBT OPEN)

- - - 19 - 28 GTG2 trips - 28 28 - - GTG2gen =19 0 19# C1

76 GTG3 trips - 19 19 - - GTG3 gen = 28 0 28 # C1

77 TPC 1

+2+3

(NEW

GIS TO

MRS3

TIE OPEN)

17.16 17.16 17.16 - - - TPC1 or 2 or

3 trips

- - - 55.2 51.5

(MRS2+

LBSS+

CCR)

17.16 55.2-34.32

= 20.88

0 -

78 TPC1 + 2 or

2 + 3 or

1 + 3 trip

- - - 27.6 51.5

(MRS2+

LBSS+ CCR)

34.32 27.6-17.16

= 10.44

34.32-10.44

= 23.9

C2

VOL-2. of 123




TCE FORM NO. 329 R5

ISSUE R0

CA

SE NO

.

DESCRIPTION

(Network

determina

tion)

TPC1

MW (Measu

red)

TPC2

MW (Measu

red)

TPC3

MW (Measur

ed)

GTG1

MW (Measur

ed)

GTG2

MW (Measur

ed)

GTG3

MW (Measur

ed)

CONTINGE

NCY (interrupt to

the controller

ISLANDING

POINT(

controlle

r output)

TOTAL GEN

CAPACI

TY (MW) based on

max

generation possible

TOTAL LOAD

ON

GENER

ATORS

TOTAL

TPC CAPACIT

Y (MW)

TOTAL

LOAD

ON TPC

POWER DEFICIT =

GENERATION

LOSS MW

(measured)

SPINNING RESERVE

(Calculated

: Max-

Actual)

LOAD

SHEDDING (MW) =

POWER

DEFICIT –

SPINNING

RESERVE

LOAD

SHED

TABLE (as per

load MW

measured)

79 TPC 1 +2

or

TPC 2 +3 or

TPC 1 +3

(NEW GIS TO

MRS3

TIE OPEN)

25.75 25.75 - - - - TPC1 or 2 or

3 trips

- - - 27.6 51.5

(MRS2+

LBSS+ CCR)

25.75 27.6-25.75

= 1.85

25.75-1.85

=23.9

C2

80 TPC 1

+2+3

(NEW GIS TO

MRS3

TIE OPEN)

26 26 26 - - - TPC1 or 2 or

3 trips

- - - 55.2 78

(MRS2+

LBSS+ CCR+

RMP)

26 55.2-52 =

3.2

26-3.2 =

22.8

D1

81 TPC1 + 2 or

2 + 3 or

1 + 3 trip

- - - 27.5 78

(MRS2+

LBSS+ CCR+

RMP)

52 27.6-26 =

1.6

52-1.6 =

50.4

D1

Similar cases as above shall be applicable for dynamic contingency and load-generation balance based Load shedding scheme for following scenarios:

1. RMP plant shutdown: - Total refinery load of 69.5MW (MRS1-18.0MW, CCR-24.0MW, LBSS-14.5MW & MRS2-13.0MW) 2. CCR plant shutdown:-Total refinery load of 72.0MW(MRS1-18.0MW, RMP-26.5MW, LBSS-14.5MW & MRS2-13.0MW)

VOL-2. of 123




TCE FORM NO. 329 R5

ISSUE R0

If RMP load is less than 8 MW then RMP plant shall be considered as under shutdown. If load is more than 8 MW, then RMP plant shall be considered as running. If CCR load is less than 5 MW then CCR plant shall be considered as under shutdown. If load is more than 5 MW, then CCR plant shall be considered as running. Following cases are applicable:

i. In case of RMP or CCR plant shutdown and 3 GTGs operating in parallel with grid, LBSS feeders shall be shifted to GTG bus i.e. LBSS on Old GIS Bus1. Then in case of any grid disturbance which will be sensed by the islanding relays, the islanding point will be New GIS COBT. GTGs will feed MRS-1, LBSS and RMP or CCR (whichever is not under shutdown) loads. TPC will feed MRS-2 loads

ii. Keeping the base configuration, in case of RMP or CCR plant shutdown and GTG1 or 2 and GTG3 operating in parallel with grid, then in case of any grid disturbance which will be sensed by the islanding relays, the islanding point will be New GIS COBT. Opening of this COBT will result in islanding operation. MRS-2 & LBSS will be automatically transferred on TPC. GTG1 or 2 and GTG3 will feed MRS1 and CCR or RMP (based on which plant is shutdown)

iii. Keeping the base configuration, in case of RMP or CCR plant shutdown and GTG1 and GTG2 operating in parallel with grid, then in case of any grid disturbance which will be sensed by the islanding relays, the islanding point will be New GIS COBT. Opening of this COBT will result in islanding operation. MRS-2 & LBSS will be automatically transferred on TPC. GTG1 and GTG 2 will feed MRS1 and part CCR or RMP (based on which plant is shutdown). CCR or RMP part load shedding is based on load generation based

scheme and load priorities.

VOL-2. of 123



DESIGN BASIS FOR THE SCHEME SHEET 36 OF64

TCE FORM NO. 329 R5

ISSUE P1

ISSUE R0


(e) For each of the predefined contingency, the controller has to check the 2 Sec. old data for MW power flow for the tripped GTG or TPC or COBT or tie feeder as applicable, check the maximum generator limit MW for other GTGs, check the 2 sec old load MW power flow , check the priority for load shedding, from the load tables . The controller will calculate the load MW required to be shed based on the tripped source power flow & sharing capacity of the running sources. For the calculated load MW, the controller will identify the loads to be shed, based on the priority assigned by operator. Thus the contingency table will be updated with the load to be shed against each predefined contingency, based on 2 seconds old MW power flows (when a fault occurs, the load & generation power flow will change and the load shed calculations done based on this data will be incorrect. Hence to ensure that the data is pre fault data, 2 seconds old data to be used.). This updating of contingency table will be a continuous process. Contingency table shall be displayed on the HMI for reference which shall show the type of contingency and action to be taken by controller.

(f) When a contingency really happens i.e. a GTG or TPC or COBT or tie feeder trips, there will be an interrupt to the controller. The controller will identify the contingency and then match it with the predefined contingency and thereby it will issue shed command to the load breakers, identified under the load to be shed column in the contingency table against that particular contingency.

Tripping relays shall be considered for tripping the load CBs.

The logic diagram for implementing the above contingency based scheme is indicated in Exhibit-II.

The total time of operation of the scheme from loss of generation to shedding of requisite quantity of load shall not be more than 0.2 sec. (Including Interposing Relay (IPR) operating time and breaker opening time). The actual load shed shall be generally 10% more than the quantum of deficiency. Measurement accuracy shall be +0.5%.

(g) Find below an example illustrating the working of the scheme: Consider the analysis of 1st pre-defined contingency in table-1 above. TPC1,2,3, GTG1,2,3 are operating in parallel. In case of grid disturbance sensed by islanding relays, New GIS COBT-1/2 will be tripped. For this pre-defined contingency the controller will check the power which was flowing through New COBT. This power value will be 2 seconds old. In case the power flow is from GTG bus to TPC bus, then the opening of New COBT will cause a power deficit in the TPC island, which has to be shared/shed. In case the power flow is from TPC bus to GTG bus, then the opening of New COBT will cause a power deficit in the GTG island, which has to be shared/shed. The PLC will check the 2 sec old power flow values for the GTGs. Based on this generation and the maximum operating limit for the generators it will compute the margin available for the running generators to share the surplus load. If the total surplus load can be shared by the running generators, then there is no need for shedding load. However if this is not the case then after computing the part of total surplus load which can be shared by generators, the balance

VOL-2. of 123




TCE FORM NO. 329 R5

ISSUE P1

ISSUE R0


surplus load shall be shed. In case the running generators cannot share any part of the surplus load then the total surplus load need to be shed. Finally the controller arrives at the amount of surplus load to be shed as per load table A2 for this contingency. Then based on the 2 seconds old load power flow, the controller determines the total load to be shed based on the priority. The total load computed will be equal to or greater than the power deficit. If suppose at the instant of this contingency analysis the generation data(2 seconds old) is as given below


ACTUAL GEN (TRANSDUCER READING) EVERY 2 SEC DATA


GTG1 19 19 0

GTG2 19 19 0

GTG3 28 28 0

TPC1 27.6 10 17.6

TPC2 27.6 10 17.6

TPC3 27.6 10 17.6


NA 2.5 (from TPC bus to GTG bus)

-


NA Open -


NA 10.75 (from MRS3 to New GIS)

-


NA 10.75(from MRS3 to New GIS)

-

LOAD DATA TABLE A2 (2 seconds old) is as below CONTINGENCY: NEW COBT OPENS, POWER FLOW THROUGH NEW COBT WAS FROM TPC BUS-2 TO GTG BUS-1 LOAD SHED = COBT POWER FLOW - TOTAL GTG RESERVE GENERATION

VOL-2. of 123




TCE FORM NO. 329 R5

ISSUE P1

ISSUE R0


PRIORITY

FOR

SHEDDING

SUBSTATION PLANT DETAILS kV

VOLTAGE

MW LOAD (

ACTUAL AS

PER

TRANSDUCER

READING) *

8 CCR Unit 142 PSA

Recycle

Compressor

6.6 2.59

9 CCR Unit 142 Tail Gas

Export

Compressor

6.6 0.36

10 CCR Unit 141B

Regeneration

Loop Compressor

(Main & Standby)

6.6 0.469

11 CCR Unit 141B

Regeneration

Loop Drier

0.415 0.612

12 CCR Unit 141B

Reduction Heater

0.415 0.486

13 CCR Unit 141B

Burning Heater

0.415 0.534

14 CCR Unit 141B

Oxychlorination

Heater

0.415 0.042

15 CCR Unit 141B

Calcination

Heater

0.415 0.0756

16 CCR Unit 141B

Nitrogen

Compressor

0.415 0.053

17 RMP CDU/VDU 6.6 7.0

18 RMP BBU 6.6 1.1

19 RMP LOBS 6.6 1.3

* In case of 2 nos. feeders to the same load, the MW shall be addition of the two. As seen from the generation data, .the power deficit due to New COBT opening will be 2.5 MW. No additional load can be shared amongst running generators GTG1, 2 or GT3 as they are operating at their max limits. Hence 2.5 MW surplus load has to be shed. The loads which will be shed will be determined based on the load table selected for this contingency (Table A2 for the load fed from GTG island,i.e CCR & RMP). As seen from table A2 above, the first entry i.e load no. 8 , CCR Unit 142 PSA Recycle Compressor is 2.59MW which is > power deficit, hence this load can be shed .

Hence the contingency table is updated based on above data and the load to be shed value is kept ready as below:

VOL-2. of 123




TCE FORM NO. 329 R5

ISSUE R0

FILE NAME: Islanding & Load shedding spec.doc_RO

CA

SE NO

.

DESCRIPTION

(Network

determina

tion)

TPC1

MW (Measu

red)

TPC2

MW (Measu

red)

TPC3

MW (Measur

ed)

GTG1

MW (Measur

ed)

GTG2

MW (Measur

ed)

GTG3

MW (Measur

ed)

CONTINGE

NCY (interrupt to

the controller

ISLANDING

POINT(

controlle

r output)

TOTAL GEN

CAPACI

TY (MW) based on

max

generation possible

TOTAL LOAD

ON

GENER

ATORS

TOTAL

TPC CAPACIT

Y (MW)

TOTAL

LOAD

ON TPC

POWER DEFICIT =

GENERATION

LOSS MW

(measured)

SPINNING RESERVE

(Calculated

: Max-

Actual)

LOAD

SHEDDING (MW) =

POWER

DEFICIT –

SPINNING

RESERVE

LOAD SHED

TABLE (as

per load MW

measured)

1

TPC1+2+

3 IN PARALL

EL WITH

GTG1+2+3

10 10 10 19 19 28

Grid

disturbance

(islanding relays

operated)

NEW

COBT 66

MRS1+RMP+

CCR=

68.5

82.8

MRS2+

LBSS=27.5

Power flow

through COBT

= -2.5 (from TPC bus to

GTG bus)

0 in GTG

island

2.5 in GTG

island

Shed load no. 8 as per table A2: - CCR PSA Recycle

Compressor (2.59 MW)

Now in reality, when the islanding relays operate and trip New COBT, the load shedding controller gets an interrupt, it identifies the contingency matches it with the pre-defined contingency in above table and gets the data regarding which load to be shed. The controller thereby issues the shed command to the respective load breaker. In above case, it trips CCR PSA Recycle Compressor .

The predefined contingency table is updated continuously based on the network (CB, isolator) status and the 2 second old power flows. For the particular operating configuration, all the pre-defined contingencies are analysed based on the dynamic generation & load power flows and load to be shed is identified. In reality when the contingency occurs, the load shedding controller gets an interrupt, it identifies the contingency, matches it with the pre-defined contingency and gets the data regarding which load to be shed. Thereby it issues the trip command to those loads. The total time of operation of the scheme from loss of generation to shedding of requisite quantity of load shall not be more than 0.2 sec(including Interposing Relay IPR operating time and breaker opening time)

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(h) The main features of the scheme are described below:

i) The total time of operation of the scheme from detection of loss of generation to shedding of requisite quantity of load shall not be more than 0.2 sec. (Including Interposing Relay (IPR) operating time and breaker opening time).

ii) The whole scheme shall be monitored as detailed hereunder:

The PLC shall have self-diagnostics and watch dog feature to annunciate failure

The PLC system shall have contact monitoring feature as described below only for critical breakers which initiate load shedding scheme or determine the network configuration. For this purpose the status of contacts used in the logic shall be determined by a logic combination of Normally Open (NO) and Normally Closed (NC) contacts of breakers and relays i.e., „breaker closed‟ or „relay operated‟ indication shall be obtained by checking that the „NO‟ is closed and „NC‟ is open (1,0). Similarly „breaker open‟ or „relay reset‟ shall be obtained by „NO‟ open and „NC‟ closed (0,1). The other two combinations i.e., both „NO‟ and „NC‟ open (0,0) or both closed (1,1) which may arise due to open circuits or short circuiting of the wires shall be rejected and used to generate an alarm

The 4 mA output of a transducer, when the power flow is zero, shall be used to monitor the health and power supply to the transducers. Its absence shall be annunciated. Failure of a transducer or the DC power input to that shall not trigger the load shedding scheme but shall set-off an alarm

To improve the speed of operation of the scheme, the breaker contacts shall be „OR‟ gated with those of the relays which directly or indirectly trip the breaker, like the trip relays of generator protection scheme and protection of associated turbines. In this way, load shedding shall be promptly initiated in the event of a turbine trip, without waiting for the operation of low forward power relay.

The transducers shall be powered through DC power supply of the respective switchgear.

Signals from field to respective RTUs and from RTUs to field shall be wired from main equipment and not from the associated control panels.

The scheme shall also have the provision for manual load shedding.

The islanding & load shedding contacts shall be potential free contacts to enable the wiring of these contacts to switchgear panels. The potential free contacts shall be wired to the marshalling panels. Additional marshalling panels shall be provided to which these potential free contacts are wired

iii) The software to be provided for load shedding application shall be real time executable program to control the overall data acquisition, display and load shedding functions.

iv) The hardware supplied under this contract shall comply with requirements of relevant IEC standards in respect of Electro- magnetic compatibility (EMC).

v) Communication between Islanding & Load Shedding Controller and the individual Data Acquisition units shall be by means of redundant data highways in Ring architecture with TCP/IP Ethernet open protocol. The

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speed shall be more than 10MBPS. vi) Communication between Controller and all the nodes (Engineering &

Operator Workstations) of the system in the Control Room shall be interconnected with a high speed LAN over minimum 100 MBPS speed Industrial Ethernet.

vii) The Hot and Standby Controllers shall be capable to operate in Hot & Standby Mode even after keeping them at two distinct locations to maximize availability and minimize common-cause failure. The distance between Hot and Standby Controllers can be up to 10 KM.

viii) The Synchronization between Hot and Standby Controllers shall be over Redundant FO Links. Synchronization should guarantee Fast Switchover time, typically 3-10 mSec, and no loss of any event.

ix) IO Modules shall be Hot-swappable ensuring minimum downtime of the system.

x) 20% Spare I/Os shall be considered for all the IOs. xi) Digital input and output terminals of Main PLC panel and RTU panel shall

be fused terminal type with LED fuse fail indication. xii) SIL (Safety Integrity Level) for the system shall be SIL-4 xiii) The electronic PCB cards shall have G3 conformal coating suitable for

use in harsh environment (Class 3) as per ISA/ANSI S71.04.1985 and IEC 654-4-1987 Class 3 environment.

j. To ensure that the frequency scheme does not operate during manual

synchronising of the running GTGs, the load shedding scheme is bypassed by using „SYNCH-IN‟ switch contact from the SCAP panel and it will also go for annunciation as “Load shedding by-passed”. After synchronising with TPC the „SYNCH-IN‟ switch position shall be brought back to „SYNCH-OUT‟ position, else the load shedding scheme will remain bypassed.

k. In the frequency stages, the higher stages will be wired for tripping the breakers of lower stages also. For e.g. if stage-1 U/F operates, then trip CB1. If stage-2 U/F operates, then trip CB1+CB2, even though, in this case stage-1 will also operate and trip CB1. As back-up, stage-2 will also trip CB1.

l. It shall be noted that all the hardware required for deriving the signals for the Islanding & Load shedding system may not have been explicitly specified in the individual equipment/system specifications and project drawings enclosed to this bidding document. The Contractor shall include all the necessary hardware required for deriving the Islanding & load shedding signals identified in the I/O list irrespective of whether they have explicitly been specified or not.

m. Future Expandability

The offered load shedding system shall have capacity such that it can cater to future addition of GTGs or loads at 6.6kV and 415V. The logic will remain the same then also, however the DI, AI & Dos will increase and the load shed table will have combination of downstream loads. The hardware like the load shedding controller, communication link, operator console should not be required to be changed when going for distributed load shedding. The software shall be capable of getting modified for the same. The speed should not be affected even for increased loads for shedding, i.e the total load shedding time of „200msec‟ shall be achieved even then.

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ISSUE P1

ISSUE R0

n. Import-Export Limiter functionality

Import-Export Limiter functionality shall be included in the islanding & load shedding system as explained below:

The controller shall continuously monitor the power flow through TPC and GTG incomers via power transducers and shall operate to keep the power import to minimum value. The controller shall issue commands to raise or lower the power generated by the GTGs to limit the import or export through the TPC lines. A selector switch shall be provided for GTG control. This switch can be located in the RTU to be provided for GTG feeders, in the CPP control room. Suppose GTG1 & GTG2 are delivering the base power and the selector switch is in GTG3 control position. The Import-Export limiter will control the generation of GTG3. As the demand in BPCL system increases, there will be import of power from TPC lines. The controller will check the value of power import with the pre-defined import limit. If the limit is exceeded, then it will issue a command to raise the generation of GTG3 to match the demand and limit the import. When the system demand increases above the capacity of one set in which case GTG3 will be delivering maximum power, the controller will give an annunciation for manual switch over to GTG1 or GTG2 position. When the switch will be put in GTG1 position, it will now match the generation of GTG1 with the demand, to ensure that there is no import of additional power above the limits from TPC system. Only when the demand increases beyond the capacity of all the operating GTGs, will additional import of power from the TPC system be allowed. When the BPCL system demand decreases, the controller will reduce the generation of GTG3 thereby ensuring that there is no export of power to the TPC system. When the system demand falls below the capacity of GTG3, in which case GTG3 will be delivering minimum power, the controller will give an annunciation for manual switch over to GTG1 or GTG2 position. When the switch will be put in GTG1 position, it will now match the generation of GTG1 with the demand, to ensure that there is no export of power from the BPCL system Alarms shall be provided in case of following scenarios in the Import-Export limiter functionality: 1. HUT-1, HUT2, HUT3 transformer capacity exceeded (GTG1, GTG2 ,

GTG3 are operating at their maximum) 2. TPC contract demand exceeded (GTG1, GTG2 , GTG3 are operating at

their maximum) 3. GTG1, GTG2, GTG3 operating at maximum generating capacity. 4. GTG1, GTG2, GTG3 operating at minimum generating capacity. 5. Changeover of GTG control required

Import Export limiter functionality shall also include following

a. Selector switch shall have position for GTG4 (future provision) b. Import & Export limit shall be settable through HMI. c. The operation of Import Export limiter shall be Inhibited on the operation of

islanding.

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ISSUE P1

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d. Output relays for Raise & lower commands to respective GTs shall be separate (for each GT) and shall be of Areva make auxiliary relay VAA type.

e. Raise / lower command to respective GT shall be through GTG selector switch and Raise or lower output relay (contact in series with raise / lower command).

o. Sequence Event Recorder (SER) & Energy Management System (EMS)

for 22kV New GIS (MRS-4)

Sequence of Events Recorder (SER) shall accept potential free signals. The system shall scan the inputs and the order of occurrences for 22kV MRS4 feeders.

The fault disturbance recorders of the numerical protection relays provided on 22kV MRS4 feeders shall be connected to the SER system for having record/trends during fault conditions.

The load managers provided in the 22kV MRS4 feeders shall be connected to the proposed system for Energy Management System and shall be expandable in future for connecting additional inputs. The load managers will be with Modbus//Ethernet port. 1 no. HMI shall be provided for SER & EMS system, loaded with the required softwares. The EMS software shall have the following minimum features: i. Data acquisition ii. Analysis & reporting (daily & monthly) iii. Real time & historical data views iv. Management of user defined alarms v. Creation of customized reports. vi. Programmable data logging interval vii. Energy trends in bar graphs, pie charts or line trends for any period

and any location viii. Harmonic bar-graphs, PQ report, Power outage reports ix. Auto e-mail, export of reports to MS Excel. x. Real time trend shall have max time resolution of 20 m Sec with a

storage capacity of 4 hours. Historical trend shall have time resolution of 2 min. with a storage capacity of 24 hours.

p. Time Synchronisation System:

The offered system and all its subsystems shall be time synchronized to a resolution of 1 ms within all over the system. It shall be possible to time synchronise all the nodes in offered system from a single source over the communication link. The source shall be a master clock equipped with a receiver that receives and decodes signals from a very high accuracy time standard such as a Global Positioning Satellite (GPS).

The detailed specification for all the equipment of the proposed system as above are covered in Section C2 ahead.

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ISSUE R0

The system architecture for Islanding & Load shedding scheme (ISLS), including Import-Export Limiter (IEL) functionality, Sequence Event Recorder(SER) & Energy Management System(EMS) is as indicated in Exhibit-I : TCE-6079B-EL-SK-2002 of this enquiry document. Input-Output (I/O) List for Islanding & Load Shedding (ISLS), Import/Export Limiter (IEL), Sequence Event Recorder (SER) & Energy Management System (EMS) is as indicated in Table-2 & 3 below. Approximate distances between different substations to be integrated in the proposed system is as indicated in Table-4 below.

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FILE NAME: Islanding & Load shedding spec_R0.doc

ISSUE R0

Input-Output (I/O) List for Islanding & Load Shedding (ISLS), Import/Export Limiter (IEL), Sequence Event Recorder (SER) & Energy Management System (EMS)

Table-2: - Total I/O count ( Typical I/Os per feeder are indicated in Table-3)

Table-2

Item Description Islanding & Load shedding,

Import/Export Limiter

Sequence Event Recorder SER Energy

Management

system

Digital

Input

Digital

Output

Analogue

Input

Digital

Input

Modbus / IEC 103/

61850 protocol

(disturbance

record from relays)

Ethernet

connection from

Load Managers

RTU IN New GIS Substation (MRS-4)

22kV New GIS

TPC HUT-1 8 2 1 7 1 1

TPC HUT-2 8 2 1 7 1 1

TPC HUT-3 8 2 1 7 1 1

GTG4 (future) 8 2 1 7 1 1

COBT1 8 2 1 7 1 1

COBT2 8 2 1 7 1 1

Bus-coupler-1 8 2 - 7 1 1

Bus-coupler-2 8 2 - 7 1 1

Tie-1 to Old GIS 8 2 1 7 1 1

Tie-2 to Old GIS 8 2 1 7 1 1

Tie-1 to MRS3 8 2 1 7 1 1

Tie-2 to MRS3 8 2 1 7 1 1

Outgoing-1 to MR2 8 2 1 7 1 1

Outgoing-2 to MR2 8 2 1 7 1 1

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ISSUE R0




Management

system

Digital

Input

Digital

Output

Analogue

Input

Digital

Input

Modbus / IEC 103/

61850 protocol

(disturbance

record from relays)

Ethernet

connection from

Load Managers

Outgoing-1 to CCR 8 2 1 7 1 1

Outgoing-2 to CCR 8 2 1 7 1 1

Outgoing-1 to DHT(future) 8 2 1 7 1 1

Outgoing-2 to DHT(future) 8 2 1 7 1 1

Outgoing-1 (Spare) 8 2 1 7 1 1

Outgoing-2 (Spare) 8 2 1 7 1 1

Total

160 40 18 140 20 20

Islanding

relays

TPC HUT-1 Primary side U/F+Td operated 1 - - - - -

TPC HUT-2 Primary side U/F+Td operated 1 - - - -

TPC HUT-3 Primary side U/F+Td operated 1 - - - -

TPC HUT-1 Secondary side U/F+Td

operated

1 - - - -


operated

1 - - - -


operated

1 - - - -

TPC HUT-1 Primary side U/F+df/dt

operated

1 - - - -


operated

1 - - - -


operated

1 - - - -

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ISSUE R0




Management

system

Digital

Input

Digital

Output

Analogue

Input

Digital

Input

Modbus / IEC 103/

61850 protocol

(disturbance

record from relays)

Ethernet

connection from

Load Managers

TPC HUT-1 Secondary side U/F+dfd/t

operated

1 - - - -

TPC HUT-2 Secondary side U/F+df/dt

operated

1 - - - -

TPC HUT-3 Secondary side U/F+df/dt

operated

1 - - - -

TPC HUT-1 Primary side O/F+Td operated 1 - - - -



TPC HUT-1 Secondary side O/F+Td

operated

1 - - - -


operated

1 - - - -


operated

1 - - - -

TPC HUT-1 Primary side O/F+df/dt

operated

1


operated

1


operated

1

TPC HUT-1 U/V+DOC+Td operated 1 - - - -


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ISSUE R0




Management

system

Digital

Input

Digital

Output

Analogue

Input

Digital

Input

Modbus / IEC 103/

61850 protocol

(disturbance

record from relays)

Ethernet

connection from

Load Managers


TPC HUT-1 U/V+DOC+dv/dt operated 1 - - - -

TPC HUT-2 U/V+DOC+dv/dt operated 1 - - - -

TPC HUT-3 U/V+DOC+dv/dtoperated 1 - - - -

TPC HUT-1 primary side

Frequency+Voltage relay

1 1



1 1



1 1

TPC HUT-1 secondary side Frequency

relay

1 1


relay

1 1


relay

1 1

TPC HUT-1 secondary side DOC relay 1 1

TPC HUT-2 secondary side DOC relay 1 1

TPC HUT-3 secondary side DOCrelay 1 1

Total

27 9 9

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ISSUE R0




Management

system

Digital

Input

Digital

Output

Analogue

Input

Digital

Input

Modbus / IEC 103/

61850 protocol

(disturbance

record from relays)

Ethernet

connection from

Load Managers

Load Shedding

relays

Old GIS Bus-1A Frequency stage-1 to stage

5 operated

5 - - - - -

Old GIS Bus-1B Frequency stage-1 to stage

5 operated

5 - - - - -

Old GIS Bus-2A Frequency stage-1 to stage

5 operated

5 - - - - -

Old GIS Bus-2B Frequency stage-1 to stage

5 operated

5 - - - - -

Old GIS Bus-1A Frequency relay operated - - - 1 1 -

Old GIS Bus-1B Frequency relay operated - - - 1 1 -

Old GIS Bus-2A Frequency relay operated - - - 1 1 -

Old GIS Bus-2B Frequency relay operated - - - 1 1 -

Total

20 4 4

RTU in Old GIS Substation

22kV Old GIS GTG3 8 2 1 - - -

COBT1 8 2 1 - - -

Bus-coupler-1 8 2 - - - -


Tie-1 to New GIS 8 2 1 - - -

Tie-2 to New GIS 8 2 1 - - -

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ISSUE R0




Management

system

Digital

Input

Digital

Output

Analogue

Input

Digital

Input

Modbus / IEC 103/

61850 protocol

(disturbance

record from relays)

Ethernet

connection from

Load Managers

Tie-1 to MRS3 8 2 1 - - -

Tie-2 to MRS3 8 2 1 - - -

Outgoing-1 to RMP 8 2 1 - - -

Outgoing-2 to RMP 8 2 1 - - -

Outgoing-1 to LBSS 8 2 1 - - -

Outgoing-2 to LBSS 8 2 1 - - -

Outgoing-1 (Spare ) 8 2 1 - - -

Outgoing-2 (Spare) 8 2 1 - - -






Total

152 38 17 - - -

22kV MRS3 GTG1 4 2 1 - - -

GTG2 4 2 1 - - -



Tie-1 to New GIS 4 2 1 - - -

Tie-2 to New GIS 4 2 1 - - -

Tie-1 to Old GIS 4 2 1 - - -

Tie-2 to Old GIS 4 2 1 - - -

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ISSUE R0




Management

system

Digital

Input

Digital

Output

Analogue

Input

Digital

Input

Modbus / IEC 103/

61850 protocol

(disturbance

record from relays)

Ethernet

connection from

Load Managers

Outgoing-1 to MRS1 4 2 1 - - -



Outgoing-1 (Spare ) 4 2 1 - - -


Total

52 26 11 - - -

6.6kV MRS2 Outgoing to SWH-5 3 2 1 - - -

Total

3 2 1

RTU in LBSS Substation

6.6kV LBSS Outgoing-1 to HCP 3 2 1 - - -

Outgoing-2 to HCP 3 2 1 - - -

Outgoing-1 to ARU 3 2 1 - - -

Outgoing-2 to ARU 3 2 1 - - -

Outgoing-1 to HVU 3 2 1 - - -

Outgoing-2 to HVU 3 2 1 - - -

Outgoing-1 to CRU/NSU/HDS/TDU/Pump

house-6

3 2 1 - - -

Outgoing-2 to CRU/NSU/HDS/TDU/Pump

house-6

3 2 1 - - -

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ISSUE R0




Management

system

Digital

Input

Digital

Output

Analogue

Input

Digital

Input

Modbus / IEC 103/

61850 protocol

(disturbance

record from relays)

Ethernet

connection from

Load Managers

Outgoing to Old Hydrogen motor-1

(assumed)

2 1 - - - -


(assumed)

2 1 - - - -

Total

28 18 8

415V LBSS Outgoing to Old Hydrogen motor-1

(assumed)

2 1 - - - -


(assumed)

2 1 - - - -


(assumed)

2 1


(assumed)

2 1


(assumed)

2 1


(assumed)

2 1

Total

12 6

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Management

system

Digital

Input

Digital

Output

Analogue

Input

Digital

Input

Modbus / IEC 103/

61850 protocol

(disturbance

record from relays)

Ethernet

connection from

Load Managers

RTU in CCR Substation

6.6kV CCR Outgoing to Unit 142 PSA Recycle

Compressor

2 1 - - - -

Outgoing to Unit 142 Tail Gas Export

Compressor

2 1 - - - -

Outgoing to Unit 141B Regeneration Loop

Compressor (Main)

2 1 - - - -

Outgoing to Unit 141B Regeneration Loop

Compressor (Standby)

2 1 - - - -

Total

8 4 -

415V CCR Outgoing to Unit 141B Regeneration Loop

Drier

2 1 - - - -

Outgoing to Unit 141B Reduction Heater 2 1 - - - -

Outgoing to Unit 141B Burning Heater 2 1 - - - -

Outgoing to Unit 141B Oxychlorination

Heater

2 1 - - - -

Outgoing to Unit 141B Calcination Heater 2 1 - - - -

Outgoing to Unit 141B Nitrogen

Compressor

2 1 - - - -

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ISSUE R0




Management

system

Digital

Input

Digital

Output

Analogue

Input

Digital

Input

Modbus / IEC 103/

61850 protocol

(disturbance

record from relays)

Ethernet

connection from

Load Managers

Total 12 6 -

RTU in RMP Substation

6.6kV RMP Outgoing to CDU/VDU 3 2 1 - - -

Outgoing to BBU 3 2 1 - - -

Outgoing to LOBS 3 2 1 - - -

Total

9 6 3

RTU in CPP Control Room

GTG control &

relay panel

GTG selector switch 1 - - - - -

GTG1 frequency raise - 1 - - - -

GTG1 frequency lower - 1 - - - -





GTG4(future) frequency raise - 1 - - - -

GTG4 (future) frequency lower - 1 - - - -

Total

1 8 -

GRAND TOTAL 484 154 58 153 33 20

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ISSUE R0

Table-3: - Typical I/Os per feeder




Management

system

Digital

Input

Digital

Output

Analogue

Input

Digital

Input

Modbus / IEC 103/

61850 protocol

(distrubance record

from relays)

Ethernet

connection from

Load Managers

Typical I/Os for

415V motor

feeders

CB / contactor open 1 1 - - - -

CB / contactor close 1 - - - - -

Total

2 1 - - - -

Typical I/Os for

6.6kV motor

feeders

CB / contactor open 1 1 - - - -

CB / contactor close 1 - - - - -

Total

2 1 - - - -

Typical I/Os for

6.6kV outgoing

load feeders

CB open 1 1

CB close 1 1

Local/Remote switch 1

MW transducer 1

Total

3 2 1 - - -

Typical I/Os for

22kV outgoing

CB open 1 1

CB close 1 1

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ISSUE R0




Management

system

Digital

Input

Digital

Output

Analogue

Input

Digital

Input

Modbus / IEC 103/

61850 protocol

(distrubance record

from relays)

Ethernet

connection from

Load Managers

load feeders on

Old GIS

CB trip 1


Isolator-1 open 1

Isolator-1 close 1

Isolator-2 open 1

Isolator-2 close 1

MW transducer 1

Total

8 2 1 - - -

Typical I/Os for

22kV GTG3

feeder on Old GIS

CB open 1 1

CB close 1 1

CB trip 1


Isolator-1 open 1

Isolator-1 close 1

Isolator-2 open 1

Isolator-2 close 1

MW transducer 1

Total

8 2 1 - - -

Typical I/Os for

22kV tie feeders

and COBT on Old

CB open 1 1

CB close 1 1

CB trip 1

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ISSUE R0




Management

system

Digital

Input

Digital

Output

Analogue

Input

Digital

Input

Modbus / IEC 103/

61850 protocol

(distrubance record

from relays)

Ethernet

connection from

Load Managers

GIS Local/Remote switch 1

Isolator-1 open 1

Isolator-1 close 1

Isolator-2 open 1

Isolator-2 close 1

MW transducer (Bi-directional) 1

Total

8 2 1 - - -

Typical I/Os for

22kV Bus-coupler

1 & 2 on Old GIS

CB open 1 1

CB close 1 1

CB trip 1


Isolator-1 open 1

Isolator-1 close 1

Isolator-2 open 1

Isolator-2 close 1

Total

8 2 - - - -

Typical I/Os for

22kV GTG1 & 2

feeders on MRS3

CB open 1 1

CB close 1 1

CB trip 1


MW transducer 1

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ISSUE R0




Management

system

Digital

Input

Digital

Output

Analogue

Input

Digital

Input

Modbus / IEC 103/

61850 protocol

(distrubance record

from relays)

Ethernet

connection from

Load Managers

Total

4 2 1 - - -

Typical I/Os for

22kV outgoing

load feeders on

MRS3

CB open 1 1

CB close 1 1

CB trip 1


MW transducer 1

Total

4 2 1 - - -

Typical I/Os for

22kV bus-couplers

1 & 2 on MRS3

CB open 1 1

CB close 1 1

CB trip 1


Total 4 2 - - - -

Typical I/Os for

22kV GTG4

(future) feeder on

New GIS

CB open 1 1 1

CB close 1 1 1

CB trip 1


Isolator-1 open 1 1

Isolator-1 close 1 1

Isolator-2 open 1 1


MW transducer 1

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ISSUE R0




Management

system

Digital

Input

Digital

Output

Analogue

Input

Digital

Input

Modbus / IEC 103/

61850 protocol

(distrubance record

from relays)

Ethernet

connection from

Load Managers

Protective relay operated 1

Protective relay disturbance record 1

Load Manager 1

Total 8 2 1 7 1 1

Typical I/Os for

22kV TPC HUT-

1, 2, 3 feeders on

New GIS

CB open 1 1 1

CB close 1 1 1

CB trip 1


Isolator-1 open 1 1


Isolator-2 open 1 1





Load Manager 1

Total

8 2 1 7 1 1

Typical I/Os for

22kV outgoing

load feeders on

New GIS

CB open 1 1 1

CB close 1 1 1

CB trip 1


Isolator-1 open 1 1

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Management

system

Digital

Input

Digital

Output

Analogue

Input

Digital

Input

Modbus / IEC 103/

61850 protocol

(distrubance record

from relays)

Ethernet

connection from

Load Managers


Isolator-2 open 1 1


MW transducer 1



Load Manager 1

Total

8 2 1 7 1 1

Typical I/Os for

22kV tie feeders

and COBT-1 & 2

on New GIS

CB open 1 1 1

CB close 1 1 1

CB trip 1


Isolator-1 open 1 1


Isolator-2 open 1 1





Load Manager 1

Total

8 2 1 7 1 1

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ISSUE R0




Management

system

Digital

Input

Digital

Output

Analogue

Input

Digital

Input

Modbus / IEC 103/

61850 protocol

(distrubance record

from relays)

Ethernet

connection from

Load Managers

Typical I/Os for

22kV Bus-coupler

1 & 2 on New GIS

CB open 1 1 1

CB close 1 1 1

CB trip 1


Isolator-1 open 1 1


Isolator-2 open 1 1




Load Manager 1

Total

8 2 - 7 1 1

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EQUIPMENT SPECIFICATION SHEET 62 OF 64

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TCE FORM 329 R5


TABLE-4

APPROXIMATE DISTANCES BETWEEN DIFFERENT SUBSTATIONS

FROM TO DISTANCE IN MTS.

New GIS (MRS4) Old GIS 250 Old GIS CPP Control Room 350

CPP Control Room LBSS 1100 LBSS CCR 800 CCR RMP 900 RMP New GIS (MRS4) 1150

The above table indicates only the approximate distances between the substations along the shortest route, and not the length of cable required for interconnecting the substations. The bidders are advised to visit the site and estimate the actual length of cable required.

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DESIGN REQUIRMENTS OF ISLANDING & LOAD SHEDDING SYSTEM

1.0 CODES & STANDARDS 1.1 The design, manufacture, performance and testing of all equipment, systems,

software, and services covered under this specification shall comply with all currently applicable statutes, regulations in the locality where the equipment will be installed. The equipment and systems shall also conform to the latest applicable standards. If such standards are not existing for any equipment or system, the same shall comply with the applicable recommendations of the following professional.

a) National Electricity manufacturers Association (NEMA).

b) The Institute of Electrical and Electronic Engineers (IEEE).

c) Instrument Society of America (ISA).

d) American National Standards Institute (ANSI).

e) Deutsche Industries Norman (DIN).

f) International Electrotechnical Commission (IEC).

g) International Consultative Committee on Telephone and Telegraphy (CCITT).

h) Verin Deutschar Eisecnhuttenlcute (VDE).

Nothing in this specification shall be construed to relieve the VENDOR of his responsibility.

1.2 Standards not indicated in the specification are acceptable (subject to approval be the CONSULTANT/PURCHASER) if they are established to be equal or superior to the standards indicated in the specification. The VENDOR shall furnish along with his bid English translation of all such standards to which the equipment and systems offered conform to.

1.3 In the event of any conflict between the codes and standards referred to in this specification and the requirements of this specification, the requirements of this specification shall govern.

2.0 SYSTEM CONFIGURATION

2.1 PLC based Islanding & Load shedding system shall comprise following subsystems and equipment:

(a) Data Acquisition & Monitoring System (DAMS)

(b) Interlock & Sequential Logic Control System (ISLCS).

(c) Control Engineer's Communication & Monitoring System (CCMS)

(d) Operator Structuring System (OSS).

(e) Communication System (CS). It shall also include digital communication interface for integration with external computer system.

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(f) Sequence of Events Recording System (SER) (Independent of Islanding & Load shedding scheme)

(g) Auxiliary Power System (APS)

(a) Data Acquisition & Monitoring System (DAMS): RTUS shall be provided for acquiring signals from buses at various sub stations and generating stations of the entire refinery complex and transmitting them to the main Islanding & Load shedding Controller through redundant fibre optic cables in ring configuration. RTUs shall have processor unit complete with memory and associated input/output modules. The fibre optic cable shall be armoured and routed in pre-lubricated HDPE pipes by air blowing technology. Specification of Fibre Optic cable is given Data Sheet-A.

For the Fibre Optic cable and other cabling associated with the system, existing cable trays and trenches shall be used. However, if the existing cable trays/trenches cannot accommodate any additional cables, the contractor shall provide new cable trays or trenches for the purpose.

(b) Interlock & Sequential Logic Control System (ISLCS):- The comprehensive islanding cum load shedding scheme shall be implemented by providing a Main PLC in the Islanding & load shedding panel at New 22kV GIS Substation, Hot stand-by PLC in CPP control Room and RTU‟s at various substations to be connected to the various switchgears through cables to collect analog and digital signals, and to trip the circuit breakers to effect the islanding and load shedding. These RTU‟s shall be soft linked to the Main PLC through redundant fibre optic cables in ring configuration.

(c) Control Engineer's Communication and Monitoring System (CCMS) shall perform the functions of man-machine communication for the entire power system network. CCMS shall be microprocessor based complete with processor unit, memory and VDU/key-board based man-machine interposing (MMI) equipment along with peripheral devices namely printer and bulk memory devices. One no. operator console shall be provided in Station-2 shift Elect Maintenance Officer room & one no. in CPP control room

(d) Microprocessor based Operator Structuring System (OSS) shall perform the functions of software generation and maintenance of the Islanding & Load shedding system by Maintenance Engineer's equipment having processor unit, memory, VDU/Keyboard based man-machine interposing equipment along with printer and bulk memory devices. One no. Engineering station shall be located in MRS-4.

(e) Communication System (CS) shall perform the function of communication among RTUs, ISLCS, CCMs equipment, and maintenance engineer's equipment for OSS and also within RTU. Communication system shall employ the means of signal transmission by a data bus system complete with local bus within each RTU, communication controller and main data bus system.

(f) Sequence of Events Recorder (SER) shall accept potential free signals. The system shall scan the inputs and the order of occurrences. The system shall also be capable of transferring the Data to bulk memory of control engineer's

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communication and monitoring system.

(g) Auxiliary Power System (APS) The existing 110V AC UPS power supply system will be made available for Islanding & Load shedding PLCs and processors. Bidder to indicate the total power requirement. The voltage supplies required for the proposed system shall be derived from the above power supply system by the BIDDER. Associated cabling is also included in supplier‟s scope.

All systems indicated above shall be interconnected and shall work satisfactorily taking into account all the required interconnections.

The proposed architecture for the Islanding & Load shedding System is indicated in Exhibit-I.

2.2 Criteria Governing Design Requirements

Design requirements of the system shall take into consideration following criteria:

A - Fail Safe Design B - System Availability C - Equipment Reliability D - Expandability E - User friendliness F - Fault Monitoring and Diagnostic Capability G - Redundancy Requirement.

The above requirements are elaborated further as follows:

2.2.1 Fail Safe Design

The hardware and software modules, subsystems and total system shall be designed so as to be fail safe and shall take into account IEC defined interference levels, which are normally present in power system network. In no case, shall a device or software failure or a combination of failures jeopardise the integrity of the power system or the safety of personnel. Check back before execution features shall be incorporated.

2.2.2 System Availability Requirements

i. All equipment and systems covered in this specification shall be designed for maximum reliability and availability.

ii. All equipment and systems shall be of proven design using material with well established physical and chemical properties and as appropriate to the service intended.

iii. Adequate redundancy shall be built in at various levels to increase the system availability and reliability.

iv. The system shall be designed with extensive self-diagnostics and trouble shooting features. Adequate facility shall be provided for quick repair/maintenance and on-line replacement of faulty modules. This shall not result in spurious trips. Where a major equipment/circuit status change is likely to occur when the card is pulled out, it shall be identified by VENDOR.

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v. Components used in the equipment and systems shall be designed with higher rating than required for the normal operating conditions in order to have higher availability of the system.

vi. Control system failure shall avoid system upsets and subsequent loss of application.

vii. Easy access shall be provided for all components in the equipment and systems offered to reduce the maintenance period.

viii. Total system availability shall be 99.7% and this shall be demonstrated during warranty period. Vendor shall furnish availability calculations.

2.2.3 Equipment Reliability

All equipment furnished shall be of good manufacturing quality and of high reliability. Equipment showing poor reliability record during system development and prior to final acceptance shall be replaced.

2.2.4 Expandability

i. The system must be expandable with respect to all subsystems in order to allow growth of the power system network due to addition of new circuit (s)/ equipment(s).

ii. The system supplied shall be easily configurable to allow changes at site.

iii. All software functional modules shall be reconfigurable without requiring hardware additions or modification. VENDOR shall state if any restrictions are imposed on the proposed configuration regarding:

. Type of Controller card

. Type of I/O card.

iv. VENDOR shall state if any constraints are imposed by the initially proposed system as regards to future expansion including:

. Addition of controllers,

. Addition of drive modules,

. Addition of operator interface equipment,

. Increase of communication capacity on data bus and communication equipment,

. Connection to additional computer systems,

. Addition of I/O system.

2.2.5 User Friendly

The system shall be provided with built-in help functions and be operator friendly for easy man-machine communication. It shall be possible for a control engineer without any software knowledge to program the system for any complex application easily, Debugging aids shall be provided for software testing.

2.2.6 Fault Monitoring and Diagnostic Capability

(a) All equipment shall continuously monitor themselves for internal faults and availability of redundancy. Any equipment / system failure has to

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be annunciated even as the system continues to be available through the redundant equipment.

(b) Every Individual system shall have a self-checking facility for the reliable operation of its components.

(c) A comprehensive fault monitoring system shall be provided to signal individually all types of internal faults of the control equipment at card level.

(d) Signalling and indication of faults shall include common alarms and individual alarms including interlock signals.

2.2.7 Redundancy Requirement

Redundancy of 100% shall be provided at the following levels as detailed below:

i. Processing Level

(a) Islanding & Load shedding PLC shall be fully redundant. The Hot and Standby Controllers shall be capable to operate in Hot & Standby Mode even after keeping them at two distinct locations to maximize availability and minimize common-cause failure. The distance between Hot and Standby Controllers can be up to 10 KM. The Synchronization between Hot and Standby Controllers shall be over Redundant FO Links. Synchronization should guarantee Fast Switchover time, typically 3-10 mSec, and no loss of any event.

ii. Communication Level

(a) Communication between Main PLC and the individual Data Acquisition units shall be by means of redundant data highways in Ring architecture with TCP/IP Ethernet open protocol. The speed shall be more than 10MBPS.

(b) Communication between Controller and all the nodes (Engineering & Operator Workstations) of the system shall be interconnected with a high speed LAN over minimum 100 MBPS speed Industrial Ethernet.

iii. Power Supply system

Power supply modules and distribution of auxiliary power supply to various equipment shall be fully redundant. Power supply module shall be parallel redundant so that change over from one module to other due to failure is without break. Failure of power module shall be annunciated through audio-visual alarm for timely action.

iv Remote Terminal Unit (RTU)

Processor for RTU shall be redundant. In case of failure of active unit, the changeover to standby unit shall be bumpless.

2.2.8 Protocols and Architecture

The protocols and architectures used in the Islanding & load shedding scheme shall be open type to allow unhindered expansion in the future.

2.3 FUNCTIONAL REQUIREMENTS OF REMOTE TERMINAL UNITS

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2.3.1 Each remote terminal unit/processing unit shall perform the following two functions:

(a) Acquisition and monitoring (measurement) of both analog and digital inputs pertaining to electrical systems in plant area.

(b) Control of circuits/equipment of electrical systems in plant area.

2.3.2 Data Acquisition and Monitoring systems shall process following types of

information available as its inputs

(a) Analog values measured through transducers such as current, voltage, active power, reactive power and frequency and parameters measures through sensor such as temperature.

(b) Digital commands signals such as -

i. Commands to operational equipment to take a definite position such as open/close.

ii. Commands to actuators to advance in steps in the required direction like transformer on load tap changers.

iii. Check commands.

(c) Indication signals of the following type:

i. Single state indications such as alarm and relay operation.

ii. Two state indications such as information about the status of devices/operational equipment.

iii. Numeric values such as indications regarding the position of transformers tap or setting value of relays used in protection system.

iv. Derived messages such as exceeding set values, which are generated by software during monitoring and processing of processing of process information.

v. Alarms generated within the system.

2.3.3 Sensors/Transducers

(a) Various parameters of the power system network namely voltage, current, active power/reactive power flow, frequency and temperature shall be measured. Voltage and current inputs shall be from voltage and current transformers respectively. Suitable transducers shall be provided to convert the signals suitable to I/O modules of RTU before taking into the system. All transducers related to a particular circuit shall be mounted in the respective switchgears/control and relay panels. If not possible, they shall be mounted in separate free standing/ wall mounted cabinets depending upon the space availability.

Armoured 2.5 sq. mm. multistrand copper cables shall be provided for connecting each transducer from particular CT/VTs. Output cable of transducers (4-20mA signal) shall be of armoured type shielded signal cable. This includes all cables from CTs/PTs to transducers, from transducers to RTUs/ to IPRs and from IPRs to field equipments.

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(b) Output contacts shall be ON/OFF and potential free and be adequately rated to make and carry trip coil currents of the order of 30A for a period of 3 seconds.

(c) Interposing Relays

Interposing relays shall be provided for converting the final control drive ON/OFF or OPEN/CLOSE commend outputs from RTUs/processing units to actuate the closing and opening coils of equipment like circuit breakers. Rating of operating coils of interposing relays and their contacts shall be suitable for interposing between two different voltage levels, viz, Islanding & Load shedding Panel system voltage and switchgear control voltage.

Interposing relays shall have the following features: i) The relay coils shall be rated to suit the voltage of proposed

system. ii) Contacts of IPRs shall be capable of making a current of

30A for a period of 3 seconds and shall be capable of carrying continuous currents of 5A. It is intended to wire these contacts to directly trip the circuit breakers.

iii) A reverse biased diode shall be provided across the coils of

IPRs to protect output modules of RTUs from high induced voltages.

iv) The interposing relays shall be plug in type and of a reputed

make.

2.3.4 FUNCTIONAL REQUIREMENTS OF DATA ACQUISITION AND MONITORING SYSTEM

2.3.4.1 Signal Conditioning & Monitoring

(a) Analog signal Conditioning

i. Galvanic isolation of inputs and output signals.

ii. Inputs filtering and non-liner filtering for attenuation of noise level.

iii. Amplification of low level signals.

iv. Cold junction compensation

(b) Analog signal Monitoring

i. Power supply failure monitoring due to lose plug connection, short circuit, wire break and voltage interruption.

ii. Transducer monitoring for party, wire break, live zero and end limit values.

iii. A/D conversion

iv. Fuse failure detection.

v. Communication monitoring.

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(c) Binary Signal Conditioning

i. Galvanic isolation of input and output signals.

ii. Inputs filtering for attenuation of noise level.

iii. Signal distribution for back-up control panel instrumentation/ annunciation system/other systems.

iv. Power supply to the sensors.

(d) Binary Signal Monitoring

i. Contact monitoring using the combination of normally open (NO) and normally closed (NC) contacts.

ii. Contact bounce.

iii. Power supply failure.

iv. Fail safe condition on failure of card/channel.

v. Fuse failure detection.

vi. Communication monitoring.

vii The contact monitoring shall use a logic combination of NO and NC contacts of breakers and relays i.e., „breaker closed‟ or „relay operated‟ indication shall be obtained by checking that the „NO‟ is closed and „NC‟ is open (1,0). Similarly „breaker open‟ or „relay reset‟ shall be obtained by „NO‟ open and „NC‟ closed (0,1). The other two combinations i.e., both „NO‟ and „NC‟ open (0,0) or both closed (1,1) which may arise due to open circuits or short circuiting of the wires shall be rejected and used to generate an alarm.

(e) Pulse Input Monitoring

Pulse counter overflow indication.

(f) Correction

Correction for measured signals will be applied as applicable.

(g) Signal compatibility between various equipment shall be ensured. All necessary conditioning and monitoring hardware required for the same shall be provided.

2.3.4.2 Signal Processing (Software)

The data acquisition and control processor in remote terminal unit (RTU) shall perform the following functions:

(a) Scanning of process inputs at the preset scan frequency and acquire data by driving its I/O system.

(b) Engineering unit conversion, i.e., relating the analog input signals to the actual value and units.

(c) Validation of the acquired input signals, i.e.

i. Checking whether the measured value is within high and low limits.

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ii. Mathematical and logical checking (e.g. correlating current and voltage with kW/KVAR and kVA).

(d) Other processing like addition, subtraction, multiplication, division, square root extraction, integration, limit value monitoring, linearisation and other logic functions as required.

(e) Storing the input data after validation/processed data in the local memory (RAM) of RTU with battery back-up.

(f) Digital filtering of all input signals.

(g) Generation of alarm messages and storing them in local memory.

(h) All analog input/output and calculated values, digital & pulse input/output and Boolean points shall be provided with following attributes:

i. Point identification No. (PID) ii. Point description iii. Engineering units iv. Contract status indicator v. Input status and quality indicators namely- . 'Bad' input point, . Input deleted from scanning/processing . Value substituted by control engineer . 'Suspect' value . Alarm inhibited . Point in alarm (HI, LO, HIHI, LOLO).

These input attributes shall be common through-out the proposed System.

2.3.4.3 Alarm Detection

Alarm monitoring shall be done for process variables, equipment malfunctions and control deviations. The following features shall be provided.

(a) Operating limits, viz., high limit, low limit or both high and low limits shall be assigned to specified analog inputs and calculated variables. The system shall check for violation of theses limits to detect alarm conditions. Provision shall be made for variable alarm limits also.

(b) In addition to the above operating limits, specified variables shall be assigned with trip limits, viz., high-high limit, low-low limit or both high-high and low-low limits.

(c) One or the states (0 or 1) of all high resolution digital inputs and specified low resolution digital inputs and Boolean variables shall be designated as the alarm state. Status change for digital inputs shall be checked at each scan and that of Boolean variables shall be checked as and when they are generated to detect alarm condition.

(d) Return to normal state from alarm condition shall also be detected. For analog variables (case (a) and (b)) dead-band feature shall be provided to avoid cyclic alarms.

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(e) Manual and automatic inhibition of alarms shall be provided. Manual inhibition shall be through console under keylock. Inputs which are detected as 'bad' or which originate from equipment which are 'out-of-service', shall be automatically inhibited from limit checking.

(f) The alarms shall be classified as follows:

i. Major alarms: All high resolution digital inputs and all analog inputs with HI-HI and LO-LO limits.

ii. Minor alarms: Analog inputs with HI and LO limits and low resolution digital inputs to be alarmed.

2.4 DESIGN AND PERFORMANCE REQUIREMENTS OF REMOTE TERMINAL UNITS/PROCESSING UNIT

Each Remote Terminal unit/processing unit shall consist of the following function blocks:

(a) Data acquisition and control processor.

(b) Communication processor with associated hardware interface with the data highway.

(c) Local memory to store dynamic plant data, control programs and self-diagnostic routines.

(d) Process input/output modules.

(e) Power supply module.

2.4.1 The data acquisition and control processor shall be a 16 or 32 bit processor with floating point arithmetic capability. It shall access the process I/O modules through local I/O bus and perform all required processing on the raw data. The data acquisition and control processor shall continue to perform its control functions even if the data highway communication system fails.

2.4.2 The communication processor with associated hardware shall facilitate the necessary communication with the other hardware units connected to the data highway.

2.4.3 The local memory resident in a Remote Terminal unit/processing unit shall have the following features:

(a) It shall provide the distributed database for that particular RTU/processing unit where all process variables connected to it are stored along with their attributes. It shall also facilitate storing of process value received from other RTUs/processing units for control function.

(b) It shall include suitable non-volatile memory (like EPROM, bubble memory, etc.) to store the standard software required to perform control, data acquisition and diagnostic functions. The VENDOR shall include necessary programming device in their offer.

(c) In case of volatile memory (RAM) battery backup for at least one-month duration shall be provided to preserve the memory contents. Local memory of RTU shall be Flash disk type.

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2.4.4 The system shall have sufficient operating speed, computing capability and input/output requirements.

2.4.5 The system shall be easy to operate and maintain and extendable in feature.

2.4.6 Use of different types of cards shall be restricted to a minimum, in order to optimise the inventory of spare cards.

2.4.7 The system shall provide for easy configuration control function or control algorithms through display of logic diagrams/ladder diagrams on VDUs. There shall not be any need for the user to have any in-depth knowledge of programming. The system shall be user friendly.

2.4.8 Provision shall be made to assure that loss of power in any part of the system does not result in loss of memory so that the system can be reconfigured on restoration of power.

2.4.9 The process input/output modules shall include analog input modules and digital input/output modules. They shall be interfaced to the data acquisition and control processor through suitable I/O bus. The process I/O modules shall be designed to reduce loading on processor to the extent possible.

2.5 Requirements of I/O Modules

2.5.1 Analog Input Modules

i. The following features shall be provided in analog input (AI) module.

(a) The decoding logic shall ensure that no two channels are selected simultaneously.

(b) Cross talk attenuation between selected and unselected channel shall be more than 80 dB.

ii. The Analog-to-Digital Converter (ADC) shall preferably be of successive approximation type. The following features shall be provided.

(a) Guarded input section to ensure large common mode noise rejection.

(b) Provision for ADC overflow detection.

(c) Repeatability shall be better than 0.025%

iii. Necessary signal conditioning prior to A/D conversion for analog inputs signals from commercially available transducers shall be determined and provided by VENDOR. The following hardware shall be included:

(a) Programmable gain amplifier for low level signals.

(b) Attenuators for high level signals (if any)

(c) Filters for noise rejection.

iv. The following design features shall be provided to offer protection to the analog input modules.

(a) Protection for continuous overload upto 200 percent of all inputs

ranges. Such overload on any analog input point shall not affect the accuracy of the next analog inputs in the same range.

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(b) Features to ensure that power line voltage variations upto ±10% and line frequency variation upto ±5% does not affect the accuracy of the system.

(c) Provision for isolating failed channels and for ensuring that such partial failures do not affect remaining healthy channels.

(d) Modular design to enable easy field expandability.

(e) Provision for too high accuracy reference voltages to be used for checking the accuracy of the ADC for linearity, zero drift and gain. The reference voltage shall be set at equal intervals with respect to the ADC range. This check shall be made automatically at periodic intervals not to exceed six seconds, and shall be alarmed, if conversion is out of tolerance.

(f) On line replacement of individual modules in case of failure.

(g) Surge withstand capability as per IEEE standards.

(h) Provision of suitable circuits for detecting any possible multiple selection or non-selection and indicating the error.

2.5.2 Digital Input Modules

The digital input (DI) modules shall be provided for the periodic scanning of both low resolution and high resolution digital inputs. The following design features shall be provided:

(a) Internal voltage source to convert contact state of potential free contacts, either change-over or ON-OFF into logic level signals. Possibility of surface film or contaminates on the contacts shall be considered while selecting this sources.

(b) Voltage level sensing units, with non-zero values for the binary status output.

(c) Differential input circuit to offer common mode isolation.

(d) Choice of polarity and threshold range.

(e) Buffer registers.

(f) Filtering to protect against contact bounce or electrical noise on input lines.

(g) Detection of card power supply failure.

(h) Surge withstand capability as per IEEE standards.

(i) Self-checking features for detecting faulty operation.

(j) Status indicating LEDs for each input.

(k) On-line replacement of individual modules in case of failure.

(1) Simulation facility.

2.5.3 Pulse Input Modules

The pulse input modules shall have the following features :

(a) Pules accumulation in pules accumulators/storage registers which are sufficiently large, so that they do not overflow when accumulating

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pulses which occur at the rate indicated in Date Sheet for a period equal to the maximum scan class interval.

(b) Suitable buffering of the accumulators/storage registers to enable scanning without affecting the counting operation.

(c) On-line replacement of individual modules in case of failure.

2.5.4 Digital Output Modules

The digital output module shall provide contact closure output by driving relays. The feature to be provided are as follows :

(a) On-line replacement of individual modules in case of failure.

(b) Long life, bounce free, high speed mercury wetted or dry reed relays.

(c) Surge withstand capability as per IEEE standards.

2.5.5 The system shall have 20% spare capacity for all types of process input/output modules.

2.5.6 The power supply shall be redundant type with suitable auto-changeover facility.

2.6 Function Requirements Of Interlock & Sequential Logic Control System (ISLCS) in the Proposed PLC for Islanding & Load Shedding

2.6.1 Interlock and sequential logic control system ISLCS shall perform following functions:

(a) Islanding & Load shedding scheme

2.6.2 ISLCS shall satisfy following functional requirements:

(a) The control system shall have the complete control capabilities that include sequential control, combination logic, computation, and interposing for data acquisition, data storage and retrieval.

(b) The control system shall allow VDU operation from the Control Desk (CD) through redundant main data bus. The communication within the cubical shall be through redundant cubical bus.

(c) The control system shall provide auto/manual operation facility under all operating conditions.

(d) The system shall provide open loop control using software modules as specified below:

i. The system shall provide sequence, interlock and open loop control

system through software modules.

ii. The system shall also provide the following facilities:

. Set/ reset, . Timer, . Up/down counter, . Register, . Time supervision for execution of steps,

. Monitoring of final control element position before and after issue of commands.

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(e) The logic controller modules shall have sufficient computing capacity

with memory to perform all Boolean, logical voting and on/off time delay functions. The program of logical functional algorithms shall reside in EAPROM/ EPROM memory and shall be modifiable from maintenance engineer's structuring VDU/key board. It shall interface with VDU/key board operations of control desk for operations of the individual drives.

(f) In the manual mode, it shall be possible to perform operations with the same defined permissives as meant for auto operation.

(g) Messages shall be generated to indicate the status of each STEP, missing CRITERIA for next STEP, drive status, system disturbances, etc., on VDUs mounted on control desk (CD) and shall also be printed.

(h) All operations will be performed through VDU/key board mounted on control desks. Also operations directly on the drive control modules shall be performed through control stations mounted on back-up control panels with own interlocks system, if provided.

2.7 FUNCTIONAL REQUIREMENTS OF CONTROL ENGINEER'S COMMIUNICATION AND MONITORING SYSTEM (CCMS)

2.7.1 Control Engineer‟s communication and monitoring system shall perform following functions through Control Engineer's interface equipment:

(a) Control function for open loop control through control display from VDU and key board.

(b) Display of mimic diagrams.

(c) Alarm display and alarm acknowledgement.

(d) Display of individual points data.

(e) Generation & display of trend plots.

(f) Generation/display/printing of various summaries.

(g) Generation/printing of various logs and reports.

2.7.2 Control Engineer's communication and monitoring system shall satisfy the following requirements:

(a) It shall provide the means for communication between the main data bus system and control engineers‟ equipment (i.e. VDU and Printers). This means of communication shall be fully redundant.

(b) It shall be possible to operate and control the plant equipment by use of control VDU and associated key boards.

(c) The process information shall be made available to control engineer in the form of various display and printout, either automatically or on demand by the Control engineer.

(d) The two control VDUs shall be fully assignable and interchangeable under all operating conditions and failure of any one VDU, data bus or part of data bus shall not result in loss of display or control.

(e) The display selection process shall be optimised so that the desired display can be selected by the barest minimum of key strokes by the

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control engineer. Trace ball /keyboard facility shall be provided for curser control purposes.

(f) It shall be possible to delete any input from scanning/processing or to return it to scanning/processing on demand by control engineer through control VDU. This action shall be logged on printer.

(g) It shall provide safety tagging to all equipment released for maintenance. A record of release orders, work permits and safety tags issued, clearance of release orders and removal of safety tags, etc. shall be stored in memory and automatically logged in printer, No operation shall be possible on any equipment during the time safety tags are in place.

2.7.3 Functions of CCMS:

2.7.3.1 Control displays

Control engineer shall normally control the power system network through these displays. These displays shall be organised in the form of plant overview display, group displays, process display and object display, individual input/output point display and logical function displays. It shall be possible to perform open loop control from these displays.

2.7.3.2 Control Display for open Loop Control

(a) Sequence control display shall contain a representation of sequence of chain in functional blocks. In the display the command issuing step, the step for which the criteria test is being carried out and the sequential step shall be shown. Running, waiting, monitoring time shall also be displayed.

(b) From control displays, the control engineer shall be able to initiate the sequence control and the system shall display the sequence status. Also, criteria bypass and intermediate step operation shall be possible from the control display.

(c) One display page shall be provided for each loop.

2.7.4 Mimic Diagrams

It shall be possible to display mimic diagrams, which represent various systems/sub-systems equipment of power system network in colour graphic from with associated dynamic plant information. The following features shall be provided:

(a) Dynamic information shall be updated every 1 second.

(b) It shall be possible to construct pictures containing bar charts and trends.

(c) Values of variables in alarm shall be displayed in red colour.

(d) It shall be possible to change the colour and flash the variable and equipment symbols to indicate alarm/trip and certain pre-defined operating conditions.

(e) It shall be possible to perform control actions through mimic diagrams.

2.7.5 Alarm Displays

The following facilities shall be provided:

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(a) Audible chime annunciation. The chime shall be dis-continued after acknowledgement.

(b) Push buttons on control engineer's console for alarm acknowledgement.

(c) Display of alarm messages and return to normal messages on VDU.

(d) Printing of alarm messages on printer on occurrence of fault or on demand.

(e) Alarm messages shall appear on the screen in the order of occurrence until the page is full.

(f) On occurrence of an alarm, an operator guidance message for accessing the alarm message in alarm display shall appear on the reserved space on the screen along with audible chime annunciation.

(g) An alarm display shall contain the latest 20 alarms with the older alarms (backlog) stored in memory as an additional page. Storage for minimum 5 pages of alarm shall be provided.

(h) It shall be possible to display backlog pages on demand. Shall an older page be on display on VDU and a new alarm occurs, the most recent alarm page shall re-appear automatically.

(i) All return top normal messages shall be removed by pressing 'Alarm Reset' key on control engineer's keyboard.

(j) 'Bad' inputs shall also be displayed on VDU in the area reserved for control engineer guidance messages.

(k) Any software and hardware faults detected by self-diagnostic check shall also be displayed on VDU. Alarm management system shall be provided where alarms related to particular event, equipment or within a date range etc can be viewed for analysis.

2.7.6 Alarm Message Format

The formats for displaying alarms on VDU and on printer shall be as follows:

(a) For analog inputs, the massage shall contain type of alarm (major or minor), time of occurrence, point ID number, point description, alarm type (LO, LO-LO, HI, HI-HI), alarm limit value and current value in engineering units.

(b) For digital inputs, the message shall contain type of alarm (major or minor) time of occurrence, point ID number, point description, alarm state descriptor.

(c) The point description shall be displayed in double height characters on the alarm VDU, but shall be printed in normal height on printer.

2.7.7 Alarm Printing

The system shall automatically print all the alarm messages on alarm printer in the same format as the display. The following features shall be provided:

(a) All the alarm messages shall be printed strictly in chronological order irrespective of type of alarm.

(b) Power system alarms shall be printed in different letter qualities or in different colours.

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2.7.8 Individual Point Data

(a) The display of individual analog inputs shall contain the following data:

. PID number,

. Point description,

. Current value in engineering units,

. Data quality (type status),

. Sensor /transducer tag number,

. Scan status (under scan/out of scan),

. Scan frequency,

. Current alarm status,

. Alarm limits.

(b) The display of digital inputs shall contain the following data :

. PID number,


. Current contact status (open, close),

. Data quality tag (type status),

. Sensor/transducer tag number

. Scan status (under scan/out of scan),

. Scan frequency,

. Current alarm status,

(c) The display of digital outputs shall contain the following data :

. PID number,


. Current contact status (open/close),

. Drive/device tag number, . Update status (active/blocked),

2.7.9 Time and Frequency Display

The time and power frequency shall always be displayed in a corner or reserved space on the screen.

2.7.10 Trend Plots

System shall store data for specified analog parameters and shall be able to generate and display trend plots. It shall be possible to prevent in each display upto four variables with same time axis and different 'Y' coordinate scales. No. of trend plots shall be as specified in Data Sheet-A.

2.7.11 Summaries

The system shall provide for composing the summaries of points with similar status. On the control engineer's command, a summary could be displayed/printed. The following type of summaries shall be included:

i. Summary of existing alarms, ii. 'Bad point' summary, iii Points out of scan summary, iv Summary of alarm limit changes for the day, v. Summary of substituted values, vi. Summary of System faults.

2.7.12 Logs/Reports

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All alarms and abnormal system conditions in the process shall be recorded on the hard copy device. Software shall generate the following reports in the required formats and shall be approved by PURCHESER/CONSULTANT.

(a) Periodic Logs

The system shall store values of specified parameters at hourly or half-hourly intervals in different groups (exact group will be identified later). Logs shall be printed out periodically.

(b) Shift Report

The system shall generate and print the following shift reports at the end of each shifts:

i. Summary of active alarm including 'bad input' summary.

ii. Status changes (breaker/isolator)

iii. Alarm limit changes by the operator.

(c) Daily Report

The system shall generate and print-out following daily reports at the end of each day:

. Daily maximum and minimum values with time for frequency, voltage, input (generation) flow and transfer flow.

. Summary of predefined important alarms.

(d) Monthly Report

Monthly reports shall include -

. Daily maximum and minimum values with date and time.

. Monthly maximum and minimum values with date and time.

The above reports shall be prepared for the following parameters:

- System demand

- Line flows

- System generation

- Energy consumption

- Calculated losses.

(e) System Fault Log

The system shall printout any fault detected in the system e. g. card failures, any processor failure peripheral failures, etc. immediately on occurrence of the same on printer.

(f) Power System Equipment Service Log

The following logs shall be provided:

i. Number of manual operations and fault clearances per circuit breaker.

ii. Hours logged in service and out of service per circuit breaker.

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2.8 DESIGN AND PERFORMANCE REQUIREMENTS OF CONTROL ENGINEER'S COMMUNICATION AND MONITORING SYSTEM (CCMS) AND CONTROL ENGINEER'S INTERFACE EQUIPMENT (CEIE)

Control Engineer's communication and monitoring system (CCMS) shall be fully redundant. If CCMS is based on a single Central Processing Unit (CPU), CPU shall have processor level redundancy. However, if CCMS is distributed over multiple subsystems each having its own CPU, then the CCMS shall be so configured that failure of a single CPU shall not affect the working of CCMS.

2.8.1 Central Processing Unit

The Central Processing Unit shall be a high performance processor with modular architecture, suitable for real time process applications. The minimum word length shall be as indicated in Data Sheet-A. The number of general purpose registers, hardware instruction repertoire, memory capacity and cycle time, internal and external interrupt system and the architecture shall be designed to provide enhanced process-oriented real time capabilities. High inherent reliability, self -checking, error-recovery and trouble isolating features are vital aspects of the CPU and shall be provided for. The following additional features shall be provided.

(a) The communication between CPU and peripherals shall preferably be by flexible input-output bus. The individual device drives/interfaces shall be capable of being plugged into the I/O bus, facilitating easy expansion/ upgrading by addition of devices.

(b) Direct Memory Access (DMA) between main and auxiliary memory shall be provided.

(c) The CPU hardware interrupt structure shall support multi-programming and suitable memory protection hardware shall be provided for system security.

(d) The power supply and other provision shall be provisions for full capacity of main memory and interrupt system.

(e) Power failure fail-safe mode shall be provided for the CPU. This feature shall permit automatic restart of the computer, after required time delay, on resumption of power supply.

(f) Provision shall be made for loading complete software from auxiliary storage by push button action by operator, loading shall be supervised by CPU and system re-initialisation done automatically. Necessary hardware boot strap loader shall be provided.

(g) The CPU shall have additional integrity features such as memory protection, memory error correction code scheme, arithmetic exception, privilege violation trap and non-present memory detection.

(h) The CPU shall have high speed floating point hardware for speed and accuracy of computation of single precision and double precision real operands.

(i) The CPU shall have instruction look-ahead feature for fast instruction execution.

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(j) The CPU shall have capability to handle data sizes of bit, byte, half word, word and double word.

(k) The CPU shall have both writable controls store (WCS) and alterable control store (ACS) to enhance performance on user program by allowing user expansion of the instruction set.

(l) The CPU shall be capable of modular hardware enhancement with other hardware units to increase system capability. CPU shall have very powerful instruction sets for high level statements. The instruction set shall cover wide variety of data types and addressing modes.

(m) A system control console consisting of monochrome SRT and keyboard shall be provided. This shall be used for communication with CPU and running the test and maintenance programs and during the system back-up.

(n) The CPU shall have real time clock capability to accept a time synchronisation pulse and adjust its internal clock with the pulse.

2.8.2 Memory System

(a) The main memory shall be made of state-of-the-art technology with minimum cycle time & access time and the minimum word size shall be 32 bits wide with extra error correction code (ECC) bits.

(b) The memory assembly shall have high performance memory system including memory bus controllers, refresh controllers and error corrections circuits.

(c) The main memory shall be modular and facility shall be provided for upgradation and expansion of main memory to meet future demands.

(d) Interleaving and overlapping of memory operation shall be possible by memory bus controller for enhanced capability.

(e) The memory management system shall provide memory write protect facility.

(f) Minimum required capacity shall be 128 MB.

2.8.3 Cache Memory

(a) Cache memory shall be provided to reduce the main memory access time and shall be built with high speed static memory chips (CMOS)

(b) Cache memory shall be provided for each processor. Instruction cache and operand cache shall be provided for each processor.

2.8.4 Bulk Memory Unit

(a) Bulk memory unit shall function as a storage device for all the control system software.

(b) The bulk memory unit shall be of a highly reliable, proven design with fast random access and suitable for operation in process environments. Winchester type hard disk and floppy disks for back-up shall be provided.

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(c) The disk capacity, access time, data transfer rate recoverable and non-recoverable error rate and type (fixed head-per--track or moving head design) shall be as specified in Data Sheet-A.

(d) On multi-drive systems, overlapping of positioning operations, block multiplexing and automatic sequence starting to minimise start-up current shall be possible.

(e) Lockout feature to prevent access to protected area of disk memory and fault monitoring and reporting features shall be provided. Auto-restart on power resumption in case of power supply failure, speed regulation to minimise effects of variation of power supply voltage and frequency and interlock to prevent physical access to disk when it is operating shall be provided.

(f) Bulk memory shall have device controller and direct memory access facility (DMA).

2.8.5 Control Engineer's Interface Equipment

2.8.5.1 Colour Graphics Video Display Unit (VDU)

The colour graphic video display unit (VDU) shall essentially consist of a display monitor(s). When used as an input-output device, it will have an associated keyboard for data/function entry. The VDU shall be designed for continuous 24 hours trouble-free operation, with easily replaceable modules.

(a) Display Monitor (LED type)

The display monitor shall be an industry grade, field proven, high resolution LED monitor, The following design features shall be provided:

i. The character size, structure, colours and brightness of the display shall be chosen so as to enable clear viewing in the maximum illumination levels in a control room without frequent adjustment/tuning.

ii. The display shall be stable, flicker-free, with good contrast, without distortion, without glare and reflection and with long life.

iii. The screen size of VDUs shall be 53 cms and shall be flat screen type.

(b) Controller

The control unit for the control monitor shall have sufficient local memory to store the background information to be displayed on the monitor. Controller connected to process information computer shall have provision for memory of minimum 2 pages. In addition, features such as generation of double-height characters, special symbols, graphic capability, controllable cursor, multi-colour capability, hardware linking, etc., shall be provided. It shall be capable of driving two Compact disk- Read/Write units.

2.8.5.2 Keyboard

The keyboards shall be provides for each display monitor.

a) Control engineers keyboard - This keyboard shall provide operator

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interface to the process for plant control and display function to access plant data in conjunction with the control monitors.

b) Maintenance engineer's keyboard - This shall enable the maintenance engineer to develop graphic displays, control system, software and system configuration for the distributed processing system.

The design features provided shall include but not be limited to the following:

i. Alphanumeric keys.

ii. Key-lock switch control over critical system functions.

iii. Page and cursor control keys and track ball.

iv Pre-defined function keys for various functions according to the type of keyboard.

v. Alarm acknowledge and cancel keys.

2.8.5.3 Printers: one Color dot matrix printer and one color laser printer.

The printers shall function as output devices.

Dot Matrix printer shall be provided for Alarm messages.

Laser printer – This printer shall facilitate printing of logs, reports, operator requested output, sequence of events printing, etc. Paper size shall be A3.

2.8.5.3.1 The printer shall have following general features:

(a) Design for continuous trouble free operation, with a minimum of maintenance.

(b) Quiet operation suitable for location in control room.

(c) Character from and spacing to present a pleasing and easily readable output.

(d) Easy maintainability, with provision for ease of execution of routine tasks such as ribbon changing, paper insertion, etc.

(e) Control unit with all error detection, error reporting and fail-safe facilities.

(f) Off-line mode selector switch to enable safe maintenance.

2.8.5.4 Compact Disk Unit

The compact disk unit shall be read/ write type and interfaced to the data bus of the distributed control system. Compact disc unit for maintenance engineers operator structuring system (OSS) shall function as a storage device for developing control system software and graphic diagrams for the distributed processing modules

2.9 COMMUNICATION SYSTEM (CS)

2.9.1 Functional Requirement

2.9.1.1 The communication system shall have a main data bus for communication between various RTUs/processing units, control engineer's communication and monitoring system and maintenance engineer's equipment. It shall also include cubicle buses which are local to the RTUs/processing units. It shall

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also include digital communication interface for integration with external computer system.

(a) Main data bus shall be redundant, hot back-up and shall have redundant data bus controller. In case of failure of one bus, the other bus shall be fully capable of meeting the requirement. The failure shall be annunciated.

(b) The data bus system shall be independent of the various equipment/modules connected it.

(c) It shall be possible to carry out on line replacement of distributed modules. This shall not result in spurious trips.

2.9.2 Design and Performance Requirements

(a) The data bus system shall be designed such that the information available at any of the RTUs/processing units will be accessible to any other RTU/processing units interfaces to the data bus.

(b) The data integrity shall be protected under the plant environmental conditions.

(c) The data bus system shall support a standard protocol with extensive error checking and error recovery features.

(d) The system shall have extensive self-diagnostic checks for detection and indication of failures.

(e) The data bus shall have 25% expandability for connecting additional modules in feature.

(f) The main databus loading shall not be more than 50% of the capacity under maximum loading/worst operating conditions. Data bus loading shall be calculated taking into account the future expansion of 25% additional modules. The VENDOR shall furnish back-up calculations in support of selected data transfer rate.

(g) The data traffic in cubicle bus (local bus) shall not affect the main data bus loading.

(h) Communication controller between main data bus and cubical data bus of each RTU/processing unit shall be redundant, hot back-up type.

2.10 OPERATOR STRUCTURING SYSTEM (OSS)

2.10.1 Functional Requirements

2.10.1.1 OSS shall have following functions:

(a) Data base generation and maintenance. However, the process control functions shall be under key-lock control.

(b) Development and testing of software to perform the functions specified in this section for the function of Islanding & Load shedding System.

(c) It shall be possible to down load the software and data base from this console to the various RTUs/processing units, either through the data bus or any alternative way.

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(d) ENTER/CHANGE function for all the attributes of analog and digital I/O points, calculation and Boolean variables and constants (e.g., scan class, process range, etc.).

(e) ASSIGN/DELETE function for all the following:

i. Scanning of inputs. ii. Alarming of inputs.

(f) Display and printing of complete data base including I/0 points.

(g) Generations of graphics for mimic diagrams, control displays

(h) In addition, it shall be possible to perform all the functions specified for control engineer‟s VDUs.

(i) Testing, configuring / re-configuring of process interface cards / modules.

(j) The software utility for generation of control software shall allow software development through ladder or logic diagrams. The utility shall be user friendly and shall not require any knowledge of programming by the user.

(k) System shall have facility to analyse downtimes and time to repair system equipment faults.

2.10.2 It shall be possible to display and print the system operational status including data buses and all the processing modules/peripherals connected to it. The following features shall be provided:

(a) Over view of total system,

(b) Status of each modules,

(c) Status of peripherals /components connected to each module (e.g. VDUs, printers, I/O boards),

(d) Status of communication system,

(e) Faults detected in system through self-diagnostics. It shall also be possible to run off-line self diagnostic programmes.

2.10.2 Design And Performance Requirements

Design and performance requirements of OSS shall be same as control engineer's communication and monitoring system (CCMS) and control engineer's interface equipment.

2.11 GENERAL PERFORMANCE REQUIREMENTS OF ISLANDING & LOAD SHEDDING SYSTEM

(a) Signal Acquisition

Signal acquisition for analog, digital and pulse inputs shall have the following features:

i. All analog inputs used for monitoring only, shall be acquired with a maximum scan interval of 1 second and shall be selectable

ii. All low resolution digital inputs shall be acquired every 10 ms and high resolution input with a resolution of 1 ms.

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iii. All hardware counters accumulating pulse inputs shall be scanned every one second.

iv. Analog and digital inputs shall be time tagged as per requirement, e.g. for alarm monitoring, report generation etc.

(b) Response Time

The response time of the system under worst loading conditions shall be as follows:

i. The updating of dynamic data on displays shall be done at least every 5 sec.

ii. The keyboard command to field equipment shall be executed in less than 1 sec.

iii. The response for control engineer's request from key board for any display shall be less than 2 seconds and the display shall be completed in 3 seconds.

(c) Spare Capacity

Each processor shall have sufficient capacity for modification or extension during commissioning.

(d) Worst Loading Conditions

For Distributed Control system, the worst loading condition shall include the following tasks:

i. All process inputs scanning and processing is in progress and all the data is transmitted over the main data bus every one second.

ii. All open loop controls in operation.

iii. All output devices are in operation with rated performance / speed.

iv. Control / information request is initiated on all control VDUs.

v. In burst mode operation 100 digital alarms are generated per second for a period of 10 seconds.

(e) The total system availability shall be as per Data Sheet - A1. Detailed calculations with the help of a schematic of various sub-systems connected in series or parallel as the case may be and the MTBF and MTTR values for the various equipment shall show that required availability is possible. The method of calculation shall be as specified in IEEE standard - P1046 or equivalent. In case a standard other than IEEE is used, a copy of the relevant portions of the standard shall also be furnished.

2.12 SEQUENCE OF EVENTS RECORDER (SER)

2.12.1 Functional Requirements

2.12.1 The SER system shall be independent of the Islanding & Load Shedding System.

2.12.2 The SER system shall have the following digital input monitoring facilities:

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(a) Galvanic isolation (b) Input filtering for noise level.

(c) Contact bounce protection (d) Power supply and supply failure protection. (e) ON - line testing (f) Fuse failure detection (g) Communication monitoring

2.12.3 The status changes (also called as events) for high resolution digital inputs, which are scanned as described below, shall be reported through the sequence of events recorder. The following features shall be provided:

(a) Status change in any one of the high resolution digital inputs to a specified state shall initiate sequence-of events recording. All status changes shall be immediately transmitted along with the time of occurrence to the data bus for annunciation on alarm VDU.

(b) For the initiating event, time shall be recorded in year, month, date, hours, minutes, seconds and milliseconds. For subsequent events, time interval shall be recorded in elapsed milliseconds, relative to the initiating event.

(c) Time resolution of at least one millisecond shall be provided for time tagging the events.

(d) The system will be time synchornised with external signal from Purchaser‟s plant system.

(e) After a time interval of 30 seconds from the initiating event, it shall be assumed that one sequence of events (SOE) is over and the sequence of event record shall be transferred to a storage buffer for further processing and printing. This facility shall be reset for further data collection after the data has been transferred to the buffer as mentioned above for monitoring the next SOE record.

(f) Data for minimum 2000 events to be stored in a cyclic manner in the memory and shall be available for printing on demand.

(g) All the high resolution digital inputs to be automatically scanned on SER restart. This scanning shall be also available on demand, to update the status of all the inputs.

(h) The sequence of events (SOE) log shall contain the following:

i. Time of occurrence as described in (b) above.

ii. Point of identification

iii. Point description

iv. Status description code.

(i) The SOE log shall be printed automatically on a printer.

(j) The SOE log shall be printed / displayed in a format approved by the PURCHASER / CONSULTANT

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2.12.4 Design And Performance Requirements

The sequence of events recorder shall be micro-processor based system for scanning high resolution digital inputs and generating the sequence of events log. This log shall be printed automatically through a dedicated printer. This system shall have the following design features:

(a) All the high-resolution digital inputs shall be hardwired to the process I/O system of the SER directly without any interstage contact multiplication.

(b) Self-checking and automatic diagnostic features shall be provided.

(c) SER shall be capable of accepting an external time synchronisation pulse and synchronise its internal clock with the pulse.

2.13 FUNCTIONAL REQUIREMENTS OF CABINETS

2.13.1 System Cabinets

2.13.1.1System cabinets for the following systems shall be included in the scope of BIDDER mounted and pre-wired with the associated hardware such as plug-in-cards, power supply units, timers, relays, test instruments, test sockets etc.

(a) Remote terminal unit/processing unit

(b) Islanding & Load Shedding controller and relays

(c) Sequence of events recording system.

(d) Computer system for control engineer's communication & monitoring system

2.13.1.2Each system cabinet shall have provision for mounting 20% extra function cards, power supplies etc. and 20% spare terminals to take care of any additions in future.

2.13.1.3The system cabinets shall have front and rear doors.

2.13.1.4Degree of protection of system cabinets shall not be less than IP-54 in accordance with IS-2147. RTUs shall be capable of functioning in a non A/C environment. The VENDOR shall guarantee the satisfactory functioning of the system hardware mounted on the system cabinets even in the event of failure of air-conditioning unit. VENDOR shall furnish the duration for which system hardware mounted on system cabinets can function satisfactorily in the absence of air-conditioned environment

2.13.1.5System cabinets internal wiring shall be solderless type (i.e. wire wrap technology)

2.13.1.6Each system cabinet shall be provided with fire / temperature detectors.

2.13.1.7These systems shall be suitable for bottom cable entry through fire retardant spray compound to be supplied by VENDOR.

2.13.1.8 Heat generating sources shall be preferably located at the top.

2.14 DESIGN AND PERFORMANCE REQUIREMENTS OF SOFTWARE

(a) The software shall consist of various utilities as described in Data sheet-A.

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(b) The online Real Time Operating System (RTOS) supplied shall be proven for similar application and shall be able to support all the equipment / peripherals.

(c) The background executive shall enable software development in background time sharing mode by two or more programmes simultaneously. It shall be possible to run / test any program without making it into an online program.

(d) Compiler if used shall generate an optimised machine language code.

(e) The file handling utility shall allow copying of one file in part or whole into another, copying from one medium to another medium and typing the file contents or VDU without entering edit mode.

(f) The utility for copying of files from magnetic tape to disk and vice versa shall have capability to read / write in both ASCII/EBCDIC mode. It shall also have capability to read from one medium in any one mode and write on another medium in different mode. It shall also have the capability to do a backup of disk on tape.

(g) The debugging utility shall allow for online debugging of programmes.

(h) The display generation utility shall be of interactive type. There shall be no need to write programmes for generation and maintenance of displays.

(i) It shall be possible to make the system backup copy and programme changes while the system is online. There shall be no need to take the system in stand alone mode for making the backup copy and programme changes.

(j) Test programmes shall be provided for hardware testing of CPU and other equipment. It shall be possible to test the equipment, except CPU and disks, without taking the system in stand alone mode. Online error checking and diagnostic message facility for CPUs various equipment shall be provided.

(k) It shall be possible to do the system generation at site after any addition or deletion in memory and peripherals.

(l) Utility shall be provided for generation and maintenance of plant input data base. The plant input data base implemented in the system shall be the master data base.

(m) The data acquisition, processing and alarm monitoring / reporting software resident in each RTU shall enable processing of raw process data including engineering unit conversion and process alarm limit checking.

(n) The communication package shall enable data transfer between the distributed modules though the data bus system.

(o) The operator interface software shall enable the operator to call up displays and to control the process through VDU/keyboard.

(p) The control language shall be a user oriented language to formulate control systems.

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(q) Report /display generator shall facilitate creation of reports and graphic displays in user definable formats.

(r) The report processor shall assess the plant database for necessary data and initiate printing of log and report.

(s) The diagnostic package shall enable online or off-line testing of all distributed modules as well as the data base communication system. The online diagnostics shall run during the normal functioning of the distributed modules without interfering wit the real time performance of the system. If any malfunction is detected in a module, it shall be disabled automatically and an alarm message shall be reported to the maintenance engineer.

(t) The downloading utility shall enable down loading of all programmes developed at maintenance engineer's work station to the respective distributed modules.

(u) Suitable communication software protocol for the communication link for communication between Islanding & Load shedding system and other computer system shall be provided.

2.15 DESIGN & PERFORMANCE REQUIREMENTS OF TRANSDUCERS

(a) Transducers for converting current transformer secondary currents of 1/5 A and voltage transformer secondary voltage of 110 v to 4-20 mA DC analog signals or to a suitable signal from acceptable to I/O modules of RTUs/processing unit shall be provided. Transducers shall be dual output type.

(b) The Transducers shall be either multi-purpose type microprocessor based or a single purpose zener diode network based, in which they shall be of active type.

(c) Galvanic isolation shall be provided between the input and output.

(d) In case of power measurement, the current and the voltage shall be passed to an electronic multiplier through isolating transformers. The multiplier shall be based on time division multiplication principle.

(e) Transducers shall comply with IEC 688 requirements.

2.16 DESIGN AND PERFORMANCE REQUIREMENTS OF INTERPOSING RELAYS

(a) Interposing relays shall be two element relays having suitable number of contacts for each element.

(b) Interposing relays shall be compact in size.

(c) The relay shall be compatible in all respects with respect to I/O boards of the proposed system with which it shall be interfaced.

2.17 MAINTENANCE AND TESTING REQUIREMENTS OF VARIOUS MODULES OF ISLANDING & LOAD SHEDDING SYSTEM

2.17.1 Maintenance Requirements

All equipment shall be designed for ease of maintenance to help achieve a high mean time between failures. All equipment shall be of modular design to

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assure a short mean time to repair. The following provisions shall be made:

(a) The vendor shall furnish the details of the maintenance requirements of each equipment, indicating list of parts which require regular maintenance and frequency of maintenance for these parts. Based on VENDOR's experience, documentation giving a recommended maintenance program to achieve a high MTBF for the system shall be furnished.

(b) The VENDOR shall furnish sufficient documentation to ensure efficient maintenance and trouble shooting of equipment and modules. This shall include point-to-point wiring diagrams and schematic diagrams of all electronic assemblies supplemented with concise description of theory of operation of individual sub-systems. Expected faults, trouble shooting hints, check-out lists and a list of sub-components prone to failure shall also be provided.

(c) All equipment shall have extensive self-diagnostic features, test points and clearly labelled error indication lamps which will help in speedy identification of faulty modules.

(d) Provision shall be made for isolating sub-systems/modules which are identified to be faulty, thus enabling on-line replacement without taking equipment off-line.

(e) Adequate number of test equipment like test sockets, test cables, digital voltmeters, 3-pen recorders, signal generators, card extenders, etc. shall be provided to facilitate ease in maintenance.

(f) Necessary maintenance equipment tools and special erection tools which are not specifically mentioned in the specification but are normally required for ease of maintenance and to have minimum down time, shall be supplied.

(g) Components of same function shall be as far as possible interchangeable.

(h) Standardisation concept shall be used in selecting the components for the system.

(i) All the documentation shall be in English language.

(j) All the documentation shall be provided on compact disk in addition to 6 copies of printed documents.

2.17.2 Testing Requirements

2.17.2.1I/O Modules Of RTU/Processing unit

(a) The analog input module shall be tested as follows:

i. Checks using simulated inputs to represent each type of input as specified in the Data Sheet

ii. Tests to determine analog input module operability, addressing capability, scan rate, linearity, repeatability and stability over a 24-hour period.

iii. Tests to determine the reproducibility of a known analog input (mid-range value).

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(b) The analog output module shall be tested as follows:

i. Checks using simulated output to represent each type of output as specified in the Data Sheet.

ii. Tests to determine analog output module operability, addressing capability, scan rate, linearity, repeatability and stability over a 24 hour period.

iii. Tests to determine the reproducibility of a known analog output (mid-range value).

(c) The digital input module shall be tested for addressing, signal level, input delay, noise rejection and interrupt recognition time.

(d) The pulse input module if applicable shall be tested for counting accuracy and capacity of the accumulator.

(e) The digital output module shall be tested to check addressing, power failure status, signal level and output delay.

2.17.2.2 Central Processing Unit

(a) VENDOR shall submit in writing for PURCHASER's review and approval a detailed description of the test procedures and programs at least two months prior to start of the system test. The tests indicated in the following paragraphs shall be included:

(b) Main memory test of twelve (12) hours duration to demonstrate the capability of memory read - write function under worst pattern at various voltage levels.

(c) Main memory parity detection test of 12 hours duration to demonstrate that parity detection feature performs properly to the PURCHASER's satisfaction.

(d) Logic tests of 12 hours duration to demonstrate the hardware commands, interrupt structures and hardware failure detection.

(e) Count-down registers and pulse counter test of eight (8) hours duration to demonstrate the accuracy of all time count-down registers.

(f) Bulk memory data transfer test of thirty-six (36) hours duration to demonstrate possible combinations of transfer from/to bulk memory including checks for illegal writing, reading and wrong transfer indications. Voltage and speed variation checks shall also be performed.

(g) Bulk memory parity detection test of 12 hours duration to demonstrate the proper functioning of the parity detection feature.

2.17.2.3 All components of RTU‟s/ BCU‟s shall be subjected to a burn in test before they are assembled. Completely assembled units (PCBs) shall be subjected to dry heat test (elevated temperature test) and Damp heat cyclic test as per IS-9000, part III & Part V. Completely assembled system shall be subjected to working test under simulated working condition at shop for a period 14 days and of which at least 72 hours shall be continuous operation performing all specified functions.

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2.17.2.4 CCMS & CEIE

CCMS & CEIE shall be tested for all performance characteristics at VENDOR's works. The following tests shall be included:

(a) Individual digits and digit selection logic of the digital display. (b) All capabilities of the VDU, including the error detection features.

(c) All keyboards shall be tested for satisfactory operation of the

keyboard, controls, push buttons and all associated functions. (d) All interlocks, performance and error detection features of the

printers. (e) Accuracy, addressing and output capability of the analog trend

recorders.

2.17.2.5 Transducers

The following tests shall be carried out for transducers:

(a) Routine test (b) Type test

2.17.2.5.1 Routine test

The following routine test shall be carried out on every transducer:

(a) Calibration and Accuracy of the Transducers at 0 - 100% rated

output burden.

(b) Power frequency H V test for the voltage level and duration

specified in Data Sheet A

(c) No- load voltage test.

(d) Ripple content of the output voltage.

(e) I R test

Tests shall be carried out as per IEC-688.

2.17.2.5.2 Type Test

One sample of each type of transducers will be tested in live conditions

monitoring input and output continuously. Type tested transducers shall

not form the part of the supply as these tests are considered destructive in

nature. The following tests shall be performed

(a) Cold test - At 5 ° C for 96 hours as per IS-9000-Part -II

(b) Dry heat test - At 55 ° C for 72 hours as per IS-9000-Part-III

(c) Dry heat Cyclic test - Two cycles at 40°C as per IS-9000-Part-V

for 12+12 hours

2.17.2.6 The equipment/materials will be inspected and testing witnessed by the PURCHASERs and their representatives. The supplier shall give at least one month‟s notice for readiness of equipment for testing at the manufacturer‟s works. The Bidder shall organize the inspection at his expense by engaging the services of Inspectors from one of the following reputed third party CLASSIFIED INSPECTING AGENCIES/SOCIETIES

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like Lloyds, IRS, BVQI, TUV, PDI, etc. The scope of inspection by inspecting agencies shall cover FAT of vendor‟s system, FAT of sub vendor supplied major components, SAT, etc. Along with the third party, the equipment/materials will be inspected and testing witnessed by the PURCHASERs and their representatives. The supplier shall give at least one month‟s notice for readiness of equipment for testing at the manufacturer‟s works. Despatch of materials to site shall be effected only after the receipt of the clearance note from inspecting agency and the despatch clearance from Purchaser.

2.17.2.7 All tests as required, both at the factory i.e. Factory Acceptance Test (FAT) before dispatch, and at site after installation i.e. Site Acceptance Tests (SAT), shall be carried out. Detailed Test reports and certificates shall be submitted. Test reports and test certificates for bought out components shall be submitted for approval. These components shall also be included in the integrated FAT.

2.17.2.8 Bidder shall furnish the list of tests, to be carried for both FAT and SAT along with test instruments to be used, with the Bid for review. Contractor shall indicate the place of FAT and the test facilities available.

2.17.2.9 The testing of all the equipment and accessories shall be carried out as per latest applicable Indian/International standards recommendations.

2.17.2.10 Prior to testing, all relevant documentation and sufficient briefing about the tests shall be given to PURCHASER‟s Engineers who would witness the testing.

2.17.2.11 Factory Acceptance Test (FAT)

i) The FAT to be performed in the factory shall include but not be limited

to the following: a) Tests for guaranteed technical parameters including total

processing time of 0.1 sec from the instant the scheme detects the opening of generator breaker to the instant trip commands are issued considering that all the loads covered under the load shedding scheme are required to be shed.

b) Integrated functional tests and burn-in tests ii) In addition, testing done during manufacturing and assembly in the

factory such as heat run, component testing, circuit testing etc. for similar equipment shall be demonstrated to the PURCHASER.

2.17.2.12 Site Acceptance Tests (SAT)

i) After installation and commissioning, the Contractor shall demonstrate, by tests in the field, compliance of the values, functionalities, quality and reliability of the complete system and its components, both hardware and software, as specified and as per guarantees. The contractor shall particularly demonstrate that the total operating time of load shedding shall not exceed 0,2 seconds (Including Interposing Relay (IPR) operating time and breaker opening time)from the instant a generator circuit breaker is signalled to be

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open by simulation to the instant load circuit breaker is opened by trip command. These tests are to be conducted without actually tripping any of the generators or loads. Hence the wires carrying trip commands are kept disconnected at respective breaker ends and spare breakers are used to conduct these tests.

ii) Contractor shall fully participate in interfacing to the equipment of others. It shall be Contractor's responsibility to ensure satisfactory functioning of the system in conjunction with related equipment like exchanges, data equipment and other communication equipment of the PURCHASER. Problems relating to such interconnections shall be mutually resolved.

iii) After tests as above, the complete system shall be on continuous uninterrupted service with all functionalities and interconnections to PURCHASER‟s equipment for 4 weeks without any failures or manual interventions for correction, modification, rectification or replacements in the Contractor's system.

iv) The conducting of these tests, and their width of coverage with respect to various features of the scheme, as also additional specific tests, if required, would be decided mutually.

2.17.2.13 Type test certificates shall be provided for all type tests as per relevant standard. Other tests routine or special shall be carried out under FAT procedures.

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DATA SHEET-A.

OVERALL SYSTEM

1.0 System Architecture Distributed Processing

2.0 Overall System Availability 99.96%

3.0 Interlock and Sequential Logic Control System (ISLCS)

3.1 Independent ISLCS required? Yes (For Islanding & Load

Shedding System)

3.2 Type of hardware (Electromagnetic

relay/solid state/PLC/PLC + µP)

PLC + µP

4.0 Back-up control panel required? No

5.0 Conventional Annunciation System

Required?

Refer section C2 write-up

6.0 Sequence of Events Recorder

Required?

Yes (Independent of Islanding

& Load Shedding System)

7.0 Sequential Control for islanding of

circuit/network in case of under-

frequency or transformer overload

trimming

Yes

8.0 System Response Time

8.1 Updating of dynamic data on display Every 5 Secs.

8.2 Key board command to field

equipment execution time

Less than 1 sec.

8.3 Key board command for display

presentation execution time

Less than 2 secs.

8.4 Key board command to display

presentation completion

3 secs.

8.5 Load shedding Operating time 0.1 secs.

REMOTE TERMINAL UNIT/

PROCESSING UNIT

1.0 No. of units As required for I/0 count

2.0 Data Acquisition & Control

Processor

2.1 Word length 32 bits

2.2 Floating point arithmetic Required

2.3 Capability to continue data

acquisition and control functions in

Required

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the absence of data highway

2.4 Input/Output capacity required

a) Analog inputs As per I/O list

b) Digital inputs As per I/O list

i. Low resolution

ii. High resolution

c) Pulse inputs As per I/O list

d) Digital outputs As per I/O list

2.5 Binary control Required

2.6 Ability for under frequency islanding

and transformer overload trimming

Required

2.7 Provision of output of time

synchronisation pulses in one of the

RTUs

Required

3.0 Dedicated Communication Processor Required

4.0 Local memory

4.1 Volatile memory

a) Type RAM

b) Type of backup Battery

c) Duration of battery backup 1 month

4.2 Non-volatile memory Required

5.0 Process Input / Output Modules

5.1 Spare capacity (implemented) 20% for each type of inputs /

outputs

5.2 Analog Input Module

5.2.1 No. of Analog inputs Refer I/O list enclosed(16

channels only per module)

5.2.2 Input range

1) 4-20 mA DC Refer I/O list enclosed

2) RTD 3-wire Refer I/O list enclosed

5.2.3 Scan cycle Shall be selectable (< 1sec)

5.2.4 Cross talk rejection Not less than 80 dB

5.2.5 Normal mode rejection ratio 120 dB

5.2.6 Common mode rejection ratio 120 dB

5.2.7 Analog to digital converter (ADC)

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a) Type Successive approximation

b) Resolution (No. of bits) 12 bits + sign bit

c) Overall accuracy 1) +0.02% FS + 1/2 LSB for

Low level inputs

2) +0.05% FS + 1/2 LSB for

High level inputs

d) Linearity Better than 0.025%

e) Repeatability Better than 0.025%

f) Input impedance 100 meg ohms

g) ADC overflow detection Required

5.2.8 Short circuit detection for analog

signals

Required

5.2.9 Optical isolation Required

5.2.10 Surge withstand capability As per IEEE standard

5.3 Digital Input Module Required

5.3.1 No. of Digital inputs Refer I/O list enclosed(16


a) Low resolution digital inputs

b) High resolution digital inputs

5.3.2 Scan cycle for low resolution digital

inputs

10 msec.

5.3.3 Contact bounce protection Required

5.3.4 Noise rejection Required

5.3.5 Differential input circuit Required

5.3.6 Choice of polarity and threshold

range

Required

5.3.7 Buffer registers Required

5.3.8 Detection of power supply failure Required

5.3.9 Surge withstand capability As per IEEE standards


5.3.11 Status indicating LED's for each

input

Required

5.4 Pulse Input Module

5.4.1 Overflow protection Required

5.4.2 Read interlock Required

5.4.3 Buffer register Required

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5.5 Digital Output Module

5.5.1 No. of digital outputs Refer I/O list enclosed(16


5.5.2 Necessary power supply Required

5.5.3 Output cycle 8 times in a second

6.0 Online replacement of cards in case

of failure

Required

7.0 Power supply units for all modules in

RTU with redundancy

Required

8.0 Degree of protection as per IS: 2147 IP-54

9.0 Technical literature Required (6-copies)

10.0 Essential spares for the following

10.1 Data acquisition & control processor

cards

Two (2) or 10% whichever is

maximum

10.2 Communication processor cards Two (2) or 10% whichever is

maximum

10.3 Local memory cards Two (2) or 10% whichever is

maximum

10.4 Process I/O cards

10.4.1 Analog input Four (4) or 10% of each type,

whichever is maximum.

10.4.2 Digital input (low resolution) Four (4) Nos. or 10% ,


10.4.3 Digital input (high resolution) Two (2) Nos. or 10% ,


10.4.4 Pulse input Two (2) Nos. or 10% ,


10.4.5 Digital Output Four (4) Nos. or 10% ,


10.4.6 Any other type of PCBs/modules not

covered above

Two (2) Nos. or 10% ,

whichever is higher

11.0 Compliance with the requirements of

Electro-magnetic compatibility

Required

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CCMS AND OSS

1.0 SYSTEM ARCHITECTURE FOR

CCMS & OSS

Distributed / Centralised

1.1 In case of centralised architecture

processor level redundancy for

CCMS

Required

2.0 DISPLAY CAPABILITIES

2.1 No. of plant overview display page As Required

2.2 No. of plant mimic display pages As Required

2.3 No. of bar chart display pages As Required

2.4 No. of individual point displays For all analog parameters.

2.5 No. of trend displays To be decided during

engineering

3.0 CENTRAL PROCESSING UNIT

3.1 Reserve capacity Minimum 20% processing

capacity under worst loading

conditions

3.2 Word length 32 bits

3.3 Arithmetic processor with floating

point capability

Required

3.4 ROM bootstrop Required

3.5 Programmable real time clock Required

3.6 Watch dog timer Required

3.7 Auto restart Required

3.8 Technical literature Required (6-Copies)

4.0 MAIN MEMORY

4.1 Type Semi-conductor

4.2 Error correction feature Required

4.3 Memory cycle time Less than 1 microsecond

4.4 Memory expandability Upto 150% of offered capacity

4.5 Battery backup Required


5.0 BULK MEMORY UNIT

5.1 Type Winchester or Fixed Disk

Drive

5.2 No. of disk drives Three; Two (2) for CCMS +

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one (1) for OSS.

5.3 No. of controllers One per drive

5.4 Formatted capacity for drive 4 GB

5.5 Data transfer rate Bidder to indicate

5.6 Average access time including

latency

Less than 40 msec.

5.7 Error checking and error recovery

feature

Required

5.8 Unit totally enclosed Required


6.0 COMPACT DISK/ DVD

UNIT(R/W)/CARTRIDGE DRIVE

6.1 No. of units Two, one [1] for CCMS and

one [1] for OSS

6.2 No of drives Two /unit

6.3 Diskette size Standard

6.4 No. of spare Diskette 5 Read/Write CDs


7.0 ESSENTIAL SPARES

7.1 CPU cards 1 set

7.2 Memory modules 2 modules

7.3 Communication module 2 modules

7.4 Any other PCB/modules One (1) No. of each type

SOFT AND HARD COPY

DEVICES FOR CCMS & OSS

1.0 COLOURS GRAPHIC VIDEO

DISPLAY UNIT (VDU)

1.1 No. of video display units Refere Exhibit-I: - System

architecture

1.2 Monitor size 53cms

1.3 No. of characters/line 80 minimum

1.4 No. of lines/display page 48 minimum

1.5 No. of colours 16 minimum

1.6 Character set details

1.6.1 Total No. of characters Min. 256 graphic characters +

ASCII

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1.6.2 No. of macro pictorial elements 64 minimum

1.7 Double height character Required

1.8 Hardware blink Required

1.9 Reverse video Required

1.10 Anti-reflection feature Required

1.11 Provision for defining dynamic

fields on screen

Required


2.0 CONTROL ENGINEER'S

KEYBOARD

2.1 No. of units One (1) No. per VDU

2.2 Alphanumeric keys Required

2.3 Control function keys for

OPEN/CLOSE, TRIP, ON/OFF

functions

Required

2.4 Dedicated display selection keys 24 minimum

2.5 Alarm acknowledgement and reset

keys

Required

2.6 Display page forward and back-ward

keys

Required

2.7 Mouse/track ball for cursor control Required


3.0 MAINTENANCE ENGINEER'S

KEYBOARD

3.1 No. of units One (1)

3.2 Alphanumeric keys Required

3.3 Page control keys Required

3.4 Cursor control Yes- Track ball/mouse shall be

provided for maintenance

Engineer's keyboard

3.5 Key lock control Required


4.0 PRINTERS

4.1 Laser Printer

4.1.1 No. of units Refer Exhibit-I:- System

architecture

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4.1.2 Type Laser

4.1.3 Printing speed Bidder to indicate

4.1.4 Selectable paper width Required

4.1.5 Selectable spacing between lines Required

4.1.6 Sound-proof enclosure Required

4.1.7 Noise level 60 db maximum (1 m from printer)

4.1.8 Local status display Required

4.1.9 Buffer memory to store atleast one line Required

4.1.10 Application a) Alarm b) Logs & reports


5.1 VDU used for control One

5.2 VDU controller card One of each type

5.3 Any other PCBs used for VDU One of each type

5.4 Control Engineer's keyboard One

5.5 Any other PCBs not covered above

and used for equipment specified in

this section

One or 10% of total whichever is

higher for type of PCB.

COMMUNICATION SYSTEM

1.0 MAIN DATA BUS SYSTEM

1.1 Type fibre optic

1.2 Standard OSI 7 Layer of ISO 7498 or

IEEE802

1.3 Type of communication protocol Any ISO or IEEE Standard

1.4 Redundant data bus Required

1.5 Self-diagnostic features Required

1.6 Error detection and recovery

features

Required

1.7 Method of communication Periodic cyclic

transmission/exception reporting

1.8 Data bus transmission rate Minimum 1 MB for cyclic

transmission and min. 250 KB for

exception reporting

1.9 Worst case data bus loading Less than 50% (BIDDER to furnish

loading calculations for proposed

configuration)

2.0 COMMUNICATION LINK FOR

COMMUNICATION WITH

Required

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ISSUE R0

EXTERNAL SYSTEM



4.1 Main data bus One full length cable (one standard

drum length along with 12 nos of

terminations)

4.2 Bus controller (if applicable) Two modules of each type

4.3 Any other PCBs in this system Two of each type

1.0 SEQUENCE OF EVENTS

RECORDER (Independent of

Islanding & Load shedding system)

1.1 No. of units One

1.2 CPU

1.2.1 Programmable real time clock Required

1.2.2 Watch dog timer Required

1.2.3 Auto restart Required

1.2.4 Time synchronisation Required

1.3 PROCESS INPUT SYSTEM

1.3.1 No. of high resolution inputs

1.3.2 Resolution One millisecond with all inputs

1.4 Redundant communication link for

data transfer to Islanding to bus

Required


2.0 SPARES

2.1 Input cards Sufficient for 20% of all inputs

2.2 CPU card One

2.3 Any other PCBs/Modules One of each type

SOFTWARE

1.0 Real time operating system Required

2.0 Background executive Required

3.0 Graphics utility Required

4.0 Assembler Required

5.0 Screen editor Required

6.0 File handing utility Required

VOL-2. of 123





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7.0 Magnetic tape /disk data transfer

utility

Required

8.0 Online debugger Required

9.0 Object module library utility Required

10.0 Report generator utility for display

and print

Required

11.0 Communication utility Required

12.0 Graphic display generation utility Required

13.0 Online system backup capability Required

14.0 Test and maintenance programs

[Diagnostic software

Required

15.0 System generation at site Required

16.0 Data base utility Required

17.0 Data acquisition, processing and

alarm monitoring /reporting

Required

18.0 Communication Required

19.0 Operator interface Required

20.0 Utilities like debugging and

software down loading program

Required

21.0 Mathematical and logic function

routines /algorithms

Required

22.0 PROJECT SOFTWARE

22.1 Plant data base Required

22.2 Control software Required

22.3 Graphic displays with points

assignment

Required

22.4 Logs or reports with points

assignment

Required

23.0 Software for communication with

external computer system

Required

BASIC PARAMETERS OF

OPTIC FIBRE

1.0 Type of fibre Monomode

2.0 Wavelength band optimised 850 nm / 1300 nm / 1550 nm

3.0 Mode field diameter 9-10 µm ±10% OF NOMINAL

VALUE

VOL-2. of 123





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4.0 Cladding Diameter 125 Micrometers ± 3

5.0 Non-concentricity core / cladding

Not More Than 2 Micrometers

6.0 Non-circularity of cladding

Not More Than 3 Micrometers

7.0 Cut-off wavelength 1200 nm

8.0 Attenuation Less Than 0.3-0.4 dB/km at 1300 nm

Less Than 0.15-0.25 dB/km at 1550

nm

TRANSDUCERS

1.0 Output range 4 - 20 mA DC

2.0 Load resistance/capability 500 Ohms

3.0 Accuracy 0.5% of full scale

4.0 Repeatability 0.1% of full scale

5.0 Linearity 0.25% of full scale

6.0 Residual ripple in output current 1% peak max.

7.0 Overload capacity a) Current transducers shall

continuously withstand 120%

of rated current and 20 time

the rated current for 1.0 sec.

Without loss of accuracy.

b) Voltage transducers shall

continuously withstand 120%

of rated voltage and twice the

rated voltage for 3.0 secs.

Without loss of accuracy

8.0 Power frequency withstand voltage 2 kV RMS for 1 minute between

wires and case

9.0 Application Islanding & load shedding

a) Current

b) Voltage

c) Watt Bi directional when power flow in

feeders is in both directions

d) VAR

e) Frequency

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f) Any other parameter, if used

10.0 No. of channels Two (2)

11.0 Applicable standard IEC 688

INTERPOSING RELAYS

1.0 Application For permissive closing of circuit

breakers, isolators and earthing

switches

2.0 Coil rating 110 V DC

3.0 Contact rating 300 V D C, continuous current

carrying capacity 5A DC

Make and carry for 3 sec : 30 A DC

Breaking capacity

- resistive DC : 100 Watts

- inductive : 50 Watts

(with L/R = 40 ms)

4.0 No of contacts 4 pairs of self reset contacts

5.0 Applicable standards a) Terminology - IS 1885

(Parts I to X)

b) Specification for electrical

relays IS-3231

c) Environmental tests and electric

equipment - IS 2106 (Parts I to

XVIII)

Note:

Power supply card, Digital input modules, Digital output modules, Analog input

module, communication module and each type of output relay shall be considered for

essential spares.

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TABLE-5

MAKES OF COMPONENTS

Item No.

Item description Make

1.0 Programmable Logic Controllers (PLCs), Remote Terminal Units (RTUs), Sequence Event Recorder (SER)

ABB, Allen Bradley, Siemens, Modicon, GE Fanuc

2.0 Ethernet Switches Siemens, Hirschmann, Entrasys

3.0 Computers & monitors: HP, DELL, Lenovo (IBM)

4.0 Distribution Board / Control Panels / JB / Marshalling panel

Hensel / Siemens / Schneider / Rittal

5.0 Dot Matrix Printer EPSON, Panasonic, TVSE

6.0 Laserjet Printer HP

7.0 Fiber Optic Cable & Patch Cords: D link, Belden, LAPP

8.0 Communication cables

LAPP cables, Udey Pyro cables, Delton cables, Associated cables, Uniflex, Belden

9.0 8. LT Power Cables

Nicco / Universal / RPG / INCAB / Polycab / LAPP / KEI / CCI

10.0 8. LT Control Cables

Nicco / Universal / RPG / INCAB / Polycab / LAPP / KEI / CCI

11.0 7 Wire Finolex / Polycab / National / LAPP / RR Kabel

12.0 Lugs Dowells / Comet

13.0 Terminals ELMEX / Connectwell / Phoenix / Wago Controls

14.0 Glands

Comet / Jainson / Braco / Baliga / R. Stahl / Siemens

15.0 Transducers ABB / Siemens/ Areva / AE/Sietex

16.0 MCB Siemens / Schneider / Legrand

17.0 HRC Fuse links L & T / Siemens/ GE Power / Bussman

18.0 Annunciators Minilec / IICP / Alstom / Yashmun

19.0 Indicating lamps (Multi chip LED type)

Binay/ Sumo

20.0 Pushbuttons Siemens / Telemecanique / Teknic / L&T / BCH

21.0 Semiconductor Fuse Areva / Siemens / Ferraz / Bussman / GE

22.0 AC Power Contactor Siemens / ABB / L&T / BCH / Telemecanique / Legrand

23.0 DC Power Contactor BCH / BHEL / Siemens

24.0 1 Auxiliary contactors Siemens / L & T / Telemecanique

VOL-2. of 123





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Item No.

Item description Make

25.0 1 Time switch GIC / Siemens / Schneider / Legrand

26.0 15.

Timers GIC / BCH / Siemens / Minilec / L&T / Schneider / Legrand

27.0 Time Delay Relay Areva / ABB / Siemens / BCH / L&T / Omron / PLA

28.0 Auxiliary Relay Areva / ABB / Jyoti / Omron

29.0 Switches & sockets (Decorative) Anchor (Roma / Ave) / Legrand / Crabtree

30.0 20 Receptacles (industrial type and non-metallic)

Legrand / Siemens / Schneider

31.0 23 Control / selector switch Kaycee / GE Power controls / Siemens / Areva /

ABB / Schneider

32.0 Change Over Switch Havells / Areva / GE Power / Siemens / L&T

33.0 3 Encoders Hubner / Honeywell / Turck

34.0 3 Limit Switch BCH / Honeywell / Siemens / Jay Balaji

35.0 UPVC Conduit Precision / Polycab

36.0 GI Conduit / Pipes AKG / Zenith / SAIL / TATA Steel

37.0 Exhaust Fan / Ventilation Fan Nadi / Usha / Almonard

38.0 31 Luminaires (Lighting Fixtures) Crompton Greaves Ltd / Bajaj Electricals Ltd. /

Wipro Lighting / Philips India Ltd.

39.0 Lamps (FTL / CFL) Philips / GE / Osram

40.0 3 Rubber Mats National

41.0 4 Auxiliary power Supply Unit Aplab / Cosel

42.0 6 Surge Protection Device OBO / Siemens / Emerson / ABB

VOL-2. of 123

SPEC. NO. TCE.M4-904

TATA CONSULTING ENGINEERS LIMITED SECTION: E

SHOP INSPECTION AND TESTS SHEET 1 OF 7

ISSUE R9

TCE FORM NO. 329 R5 FILE NAME: M4904R9.DOC

1.0 SCOPE This specification covers the requirements for Shop Inspection and Tests to be

carried out by the PURCHASER/CONSULTANT/INSPECTION AGENCY. 2.0 GENERAL 2.1 The plant and equipment covered by the PURCHASE ORDER/CONTRACT

shall be subjected to inspection and testing. The VENDOR/CONTRACTOR shall provide all services to establish and maintain quality of workmanship in his works and that of his SUB-VENDOR’s/SUB-CONTRACTOR’s works to ensure the mechanical accuracy of components, compliance with approved drawings, identification and acceptability of all materials, parts and equipment.

2.2 For supply of systems, the VENDOR/CONTRACTOR shall, at the start of the

PURCHASE ORDER/CONTRACT, furnish a total list of items in his scope of work. This list, giving a brief description of the item, quantity, names of probable SUB-VENDORS/SUB-CONTRACTORS, and a blank column for agency for final approval of drawings and documents, shall be submitted for approval by PURCHASER/CONSULTANT. The blank column shall be filled by PURCHASER/CONSULTANT. The list shall be submitted within two weeks from the date of Letter of Intent.

2.3 For systems and major items such as pressure and load bearing items,

machineries etc., the VENDOR/CONTRACTOR shall furnish quality plan giving details of checks and tests to be conducted by them on material, process, sub-assembly and assembly. These shall include requirements as prescribed in the applicable specifications, codes and statutory requirements. The quality plan shall be reviewed by the PURCHASER/CONSULTANT and the stages to be witnessed and verified shall be indicated by the PURCHASER/CONSULTANT in the approved quality plan.

2.4 The VENDOR/CONTRACTOR shall give the PURCHASER/CONSULTANT

written notice of any material being ready for testing as per format enclosed. The clear notice period shall be seven (7) days for local inspection and fifteen (15) days for outstation inspection. Such tests shall be to the VENDOR’s/CONTRACTOR's account except for the expenses of the PURCHASER/CONSULTANT. The PURCHASER/CONSULTANT, unless the inspection of the tests is virtually waived, shall fix a date for inspection with the VENDOR/CONTRACTOR and attend such tests within fifteen (15) days of the date on which the equipment is notified as being ready for test and inspection failing which, the VENDOR/CONTRACTOR may proceed with the tests and shall forthwith forward to the PURCHASER/CONSULTANT duly certified copies of tests in triplicate. If the VENDOR/CONTRACTOR fails to offer the equipment for inspection as per the agreed date, he is liable to pay for the time and expenses for the infructuous visit of the PURCHASER/CONSULTANT.

2.5 In all cases where inspection and tests are required whether at the premises or

works of the VENDOR/CONTRACTOR or of any SUB-VENDOR/SUB-CONTRACTOR or at laboratory, the VENDOR/CONTRACTOR, except where otherwise specified, shall provide free of charge all facilities such as labour,

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materials, electricity, fuel, water, stores, test bed, apparatus and instruments, laboratory tests etc. as may be required by the PURCHASER/CONSULTANT to carry out effectively such tests of the equipment in accordance with the PURCHASE ORDER/CONTRACT and shall give facilities to the PURCHASER/ CONSULTANT to accomplish testing.

2.6 The PURCHASER/CONSULTANT shall at all working hours have access to all

parts of the VENDOR’s/CONTRACTOR's and his SUB-VENDOR’s/SUB-CONTRACTOR's factory where the items of the plant are being prepared, for carrying out inspection activities as deemed necessary. A set of the relevant latest approved drawings with approval marking of the PURCHASER/ CONSULTANT and drawings for proprietary items shall be made available by the VENDOR/CONTRACTOR to the PURCHASER/CONSULTANT, for reference during inspection.

2.7 In the case of stage inspection hold points, the VENDOR/CONTRACTOR shall

proceed from one stage to another only after the component is inspected by the PURCHASER/CONSULTANT and written permission given to proceed further. The same procedure shall be adopted for any rectifications and repairs suggested by the PURCHASER/CONSULTANT.

2.8 The PURCHASER/CONSULTANT shall have the right to inspect any

machinery, material, structures, equipment or workmanship furnished or used by the VENDOR/CONTRACTOR and may reject any which is defective or unsuitable for the use and purpose intended, or which is not in accordance with the intent of the PURCHASE ORDER/CONTRACT. The VENDOR/ CONTRACTOR, upon demand by the PURCHASER/CONSULTANT, shall remedy or replace at the VENDOR’s/CONTRACTOR's expense such defective or unsuitable items of the plant, or the PURCHASER/CONSULTANT may, at the expense of the VENDOR/CONTRACTOR, remedy or replace such defective or unsuitable items of the Plant.

2.9 All principal mill test reports, the VENDOR/CONTRACTOR inspection and tests

reports, test certificates and test curves shall be supplied for all inspection and tests carried out including other records such as stress relieving charts, radiographic charts and other non-destructive testing records in accordance with the provisions of the PURCHASE ORDER/CONTRACT, duly certified by the main VENDOR/CONTRACTOR. The PURCHASER/CONSULTANT shall reserve the right to call for certificates of origin and test certificates for all raw material and equipment at any stage of manufacture.

2.10 The PURCHASER/CONSULTANT shall within fifteen (15) days from the date of

inspection as defined herein give notice in writing to the VENDOR/ CONTRACTOR of any non-conformance pertaining to all or any equipment and workmanship which in his opinion is not in accordance with the PURCHASE ORDER/CONTRACT. The VENDOR/CONTRACTOR shall give due consideration to such objections and shall either make the modifications that may be necessary to meet the said objections or shall confirm in writing to the PURCHASER/CONSULTANT giving reasons therein that no modifications are necessary to comply with the PURCHASE ORDER/CONTRACT.

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2.11 When the factory tests and documentation have been satisfactorily completed at the VENDOR’s/CONTRACTOR's or SUB-VENDOR's/CONTRACTOR's works, the PURCHASER/CONSULTANT shall issue acceptance note or shipping release note or a certificate to this effect within fifteen (15) days after completion, but if the tests are not witnessed by the PURCHASER/ CONSULTANT, the certificate or comments thereof shall be issued within fifteen (15) days of the receipt of the VENDOR’s/CONTRACTOR's test certificate by the PURCHASER/CONSULTANT. Failure of the PURCHASER/ CONSULTANT to take such an action shall not prevent the VENDOR/ CONTRACTOR from proceeding with the work. The completion of these tests or the issue of the certificates shall not bind the PURCHASER/ CONSULTANT to accept the equipment, should it, on further tests after erection, be found not to comply with the PURCHASE ORDER/CONTRACT.

2.12 None of the plant and the equipment to be furnished or used in connection with

the PURCHASE ORDER/CONTRACT shall be despatched until shop inspection, satisfactory to the PURCHASER/CONSULTANT has been made. However, such shop inspection and/or certification shall not relieve the VENDOR/CONTRACTOR of his responsibility for furnishing the plant and the equipment conforming to the requirements of the PURCHASE ORDER/ CONTRACT nor prejudice any claim, right or privilege which the PURCHASER/ CONSULTANT may have because of the use of defective or unsatisfactory items. Should the PURCHASER/CONSULTANT waive the right to inspect any item, such waiver shall not relieve the VENDOR/CONTRACTOR in any way from his obligation under the PURCHASE ORDER/CONTRACT. In the event of the PURCHASER’s/CONSULTANT's inspection revealing poor quality of goods, the PURCHASER/CONSULTANT shall be at liberty to specify additional inspection procedures, if required, to ascertain the VENDOR/CONTRACTOR's compliance with the equipment specifications.

3.0 SUB-ORDERS AND SUB-CONTRACTS 3.1 In order to facilitate the inspection of bought-out materials and plant, the

VENDOR/CONTRACTOR shall submit for approval, three (3) copies of all sub-orders and sub-contracts placed by him as soon as these are issued. Copies of any drawings referred to in the sub-order or sub-contracts shall also be submitted, unless agreed otherwise by the PURCHASER/CONSULTANT.

3.2 The sub-orders, sub-contracts and drawings referred to above shall include all

components which are subjected to electrical and mechanical pressure or stress when the plant is in operation, and also auxiliaries and spares which are to be directly despatched to site from the SUB-VENDOR’s/SUB-CONTRACTOR's works.

3.3 All sub-orders and sub-contracts of the main VENDOR/CONTRACTOR shall

clearly be marked with the main VENDOR’s/CONTRACTOR's name and the PURCHASER’s/CONSULTANT’s name and the PURCHASE ORDER/ CONTRACT reference. These shall include the following statement:

The plant or the equipment which is the subject of this PURCHASE ORDER/

CONTRACT shall comply in every respect with the requirements of the

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PURCHASER’s/CONSULTANT's technical specifications and shall be subject to inspection and tests to the satisfaction of the PURCHASER/CONSULTANT.

3.4 For the purpose of this para, it is obligatory on the VENDOR/CONTRACTOR

that he advises his SUB-VENDOR/SUB-CONTRACTOR of the pertinent clauses in this specification when ordering bought-out plant, equipment or materials. In particular, the VENDOR/CONTRACTOR shall advise every SUB-VENDOR/SUB-CONTRACTOR that he is required to supply design calculations, drawings, inspection reports and test certificates strictly in accordance with this specification and technical information for inclusion in the Instruction Manual as specified in Section E of the Enquiry Document. The SUB-VENDORS/SUB-CONTRACTORS should also be reminded that they shall include with their offer all tools and appliances necessary for proper maintenance and all spare parts in accordance with Section E of the Enquiry Document. Itemised prices of the recommended spare parts shall be submitted together with the appropriate part numbers and drawings.

3.5 Sub-ordering and sub-contracting for major items such as pressure and load

bearing items, machinery etc. can be done only with the approval of the PURCHASER/CONSULTANT.

4.0 MATERIAL TESTS 4.1 In the event of the PURCHASER/CONSULTANT being supplied with the

certified particulars of tests which have been carried out for the VENDOR/ CONTRACTOR by the supplier of material, the PURCHASER/CONSULTANT may, at his own discretion, accept the same as proper evidence of compliance with the requirements of appropriate specifications for the materials.

4.2 The VENDOR/CONTRACTOR is to provide test pieces as required by the

PURCHASER/CONSULTANT to enable him to determine the quality of material supplied under the PURCHASE ORDER/CONTRACT. If any test piece fails to comply with the requirements, the PURCHASER/CONSULTANT may reject the entire lot of material represented by the test piece.

4.3 Critical materials used in manufacture of the equipment and construction of the

plant covered by the PURCHASE ORDER/CONTRACT may also be subjected to one or more of the Non-Destructive Tests (NDT) as called for in the enquiry document or as mutually agreed. Salvaging of material due to unacceptable defect is to be attempted by the VENDOR/CONTRACTOR only after getting specific concurrence from the PURCHASER/CONSULTANT and according to the approved procedures.

5.0 WELDING 5.1 All welding involved in construction and fabrication of the plant and items

covered under the PURCHASE ORDER/CONTRACT shall be carried out in accordance with specifications and applicable codes.

5.2 Welding procedures and welders' qualifications shall be approved by the

PURCHASER/CONSULTANT. Where applicable, welders shall be tested as

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detailed in codes specified for pipe welding, vessel welding and structural welding and appropriate to the corresponding weld position using test pieces of appropriate parent metal to be used on the job. The PURCHASER/ CONSULTANT shall have the right to have any welder re-tested at any time during the PURCHASE ORDER/CONTRACT.

5.3 Recommendations of applicable codes shall be followed for non-destructive

tests, wherever applicable. 5.4 Copies of all welding procedures, procedure qualification records, welders'

performance qualification certificates, post-heating and stress relieving records, NDT records and other test results shall be made available upon request of the PURCHASER/CONSULTANT.

6.0 FABRICATION AND INSPECTION Fabrication and inspection procedures for vessels, heat exchangers, pipes,

tubes and valves etc. shall be in accordance with procurement specifications, quality plan, applicable codes or any other approved equal.

7.0 TESTS AT MANUFACTURER'S WORKS 7.1 GENERAL The tests at works shall include electrical, mechanical and hydraulic tests in

accordance with the appropriate clauses of Statutory Regulation, relevant codes and standards and approved drawings and specifications and in addition any test called for by the PURCHASER/CONSULTANT to ensure that the plant being supplied fulfils the requirements of the specifications. The VENDOR/ CONTRACTOR shall carry out all the shop tests and inspections specified under individual items of the equipment in Section-D of the enquiry document, in addition to those normally required as per codes and standards. For items not covered by any code or specifically mentioned in the specifications, the tests are to be agreed with by the PURCHASER/CONSULTANT. If considered necessary by the PURCHASER/CONSULTANT, multi-part assemblies shall be fully erected and tested in the works prior to packing and despatch to the site.

7.2 TEST CERTIFICATES Test certificates including test records, performance curves and balancing

certificates shall be supplied according to the Distribution Schedule. All the tests shall be carried out in accordance with the provisions of the PURCHASE ORDER/CONTRACT.

All test certificates must be endorsed with sufficient information to identify the

material or the equipment to which the certificates refer, and must carry at the top right hand corner the identification of the PURCHASER/CONSULTANT and the PURCHASE ORDER/CONTRACT.

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7.3 CALIBRATION All instruments used for critical measurement such as pressure gauges for leak

tests, instruments for measuring performance parameters; instruments for precision dimension measurements shall have valid calibration certificates traceable to national standards. This means that the calibrating agency engaged by the VENDOR/CONTRACTOR shall use instruments which are in turn calibrated by Government approved agencies and such information shall be recorded in the calibration certificate issued by the calibrating agency by giving the certificate number, date and date of validity of the certificate given by the Government approved agency.

FORMAT FOR INSPECTION REQUEST FROM THE

VENDOR/CONTRACTOR To, TATA CONSULTING ENGINEERS LIMITED,

Attn: Mr/Ms

PROJECT MANAGER Dear Sir/Madam, Items detailed below are ready for inspection. Please arrange inspection and

confirm the date. 1. PURCHASER 2. PROJECT 3. PURCHASE ORDER/CONTRACT

REFERENCE NUMBER

4. CONSULTANT (TCE) REFERENCE

NUMBER

5. SUB-VENDOR/SUB-CONTRACTOR 6. SUB-VENDOR’s/SUB-CONTRACTOR’s

ADDRESS

7. PLACE OF INSPECTION AND ADDRESS 8. CONTACT PERSON, PHONE, FAX AND

E-MAIL ID

9. DESCRIPTION OF ITEM AND QUANTITY 10. NATURE OF INSPECTION REQUIRED

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11. PROPOSED DATES 12. WEEKLY HOLIDAY We confirm that the items have been fully inspected and tested by us. All stages

of inspection as per approved quality plan have been carried out by us and all material test certificates, quality control records and test reports and valid calibration reports of measuring and testing instruments with traceability to national level are ready with us.

Thanking you and awaiting your confirmation, Yours faithfully, Note 1 Following clear notice periods (Date of Receipt at TCE to Date of

Inspection) are required: (a) Local Inspection - 7 days (b) Outstation Inspection - 15 days Note 2 Weekly Holidays for TCE - Saturday and Sunday cc: Purchaser cc: Sub-Vendor/Sub-Contractor

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