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Bidding Document (Volume – II)

Dakshin Haryana Bijli Vitran Nigam Limited

Due Date –10th July, 2013 14:30 HRS IST

Bidding Document Bid No-WB/DH/2013/G-04 Automatic Meter Reading System DHBVN, Haryana, India

Automatic Meter Reading System

Better Consumer Services

AT&C Loss Reduction

Bidding Document, Volume-II, SRS Document of AMR System, DHBVN

Automatic Meter Reading System Due Date: 10/07/2013 2.30 PM P a g e | 2

Table of Contents

Section 1: About DHBVN ........................................................................................................................... 3

Section 2: Scope of Work ........................................................................................................................... 4

Section 3: Pre-Qualifying Requirements .................................................................................................. 9

Section 5: Bid Features ............................................................................................................................. 17

Section 6: Technical Specifications of AMR Software ........................................................................... 40

Section 7: Technical Specifications of AMR Modems ........................................................................... 67

Section 8: Technical Specifications of IT Servers .................................................................................. 71

Technical Specification -3Ph 4 wire whole Current Meter .................................................. 74

Technical Specification -3Ph 4 wire LT CT operated & HT CT/PT operated Meter ........... 75

Technical Specification -Service Cable LT PVC ................................................................. 76

Section 9: Bill of Material ......................................................................................................................... 77

Section 10: Service Level Agreements ..................................................................................................... 79

Section 11: Estimated Man-Power Requirements ................................................................................. 83

Section 12: Estimated Timelines Requirements ..................................................................................... 85



Section 1: About DHBVN The Haryana Electricity Reform Act, 1997 (Act No. 10 of 1998) was passed by the Haryana State Legislative Assembly on 22nd July, 1997. After receiving the Presidential assent on 20th Feb.1998, this Act came into force on 14th

August, 1998. The erstwhile Haryana State Electricity Board was unbundled into two corporate bodies namely Haryana Power Generation Company Limited for the generation of power and Haryana VidyutPrasaran Nigam Limited for the transmission & distribution of power within the state of Haryana. Subsequently, the activity of distribution and retail supply of power was entrusted with effect from 1st July 1999 to Uttar Haryana Bijli Vitran Nigam for the northern circles and Dakshin Haryana Bijli Vitran Nigam for the southern circles of Haryana – Gurgaon, Faridabad, Bhiwani, Hisar, Sirsa, Narnaul & Rewari. Dakshin Haryana Bijli Vitran Nigam (DHBVN) is head-quartered in Hisar and is responsible for distribution and retail supply of electricity in the southern parts of Haryana covering the districts of Faridabad, Palwal, Gurgaon, Mewat, Mahendergarh, Rewari, Bhiwani, Hisar, Fatehabad and Sirsa.DHBVN provides services to approx. 24.7 lakh consumers of various categories. Category Wise Total Consumer Base of DHBVN in each Circle

Figures as on 01/01/2013



Section 2: Scope of Work

DHBVN intends to install Automatic Meter Reading (AMR) System on all the categories of consumers with connected load above 10 kW and Distribution Transformers of Urban Area (except agricultural consumers, and HT Consumers, Distribution Transformer covered in R-APDRP scheme). The scope of work for the Implementing Agency (IA) shall comprise of the following broad heads:

(a) Supply and installation of all the hardware and software components of Automatic Meter Reading (AMR) system that should be scalable in nature taking into consideration an average growth rate of consumers and associated infrastructure to be 7.5 % per annum for a period of 78 months from the date of contract; Enterprise-wide license for the software components is a requisite;

(b) IA will carry out Operation & Maintenance of the AMR system for a period of One (1) year post roll out free of cost as part of the supplier’s warranty and maintenance for a period of succeeding four (4) years. The maintenance will include carrying out regular and periodic field activities required for ensuring proper health of the deployed infrastructure. The supplier will also be responsible for the operations of completed phases of the system during the implementation phase.

Supply and Installation

1.2 The supply and installation shall include the following:

(a) The field equipments which shall include the DLMS Compliant meters, AMR Modems, Meter Cover Boxes, Cable for DT Meters and other requisite accessories.

(b) The proposed AMR solution shall be based on GPRS/CDMA/PLC/EDGE/Latest Proven Technologies.

(c) The Meter Data Acquisition System (MDAS) application, the server for hosting the same and other hardware and software applications which should form the base computer station (BCS). The MDAS should be a web-based application which can be accessible from remote sub-divisions, circle and regional offices. It



should have integration features with the billing servers at circle level (after implementation of R-APDRP, it should be integrated with the data center).

(d) It should also be able to furnish periodic reports detailing the performance of the consumers and the subdivision in terms of commercial and technical parameters. The actual format of the reports to be generated shall be decided by DHBVN after award of work in discussion with the implementation agency.

1.3 The ownership of the AMR infrastructure would be with DHBVN after installation and commissioning of the system. The responsibility of operating the AMR infrastructure including operation of Base Computer Station (BCS) and associated communication infrastructure shall also be with DHBVN. However, the supplier will

(a) Operate the entire AMR system including the BCS, under DHBVN’s guidance, for one year after complete roll out,

(b) Will maintain the system for a duration of 5 years from the date of successful installation and commissioning of the AMR system and

(c) Own the responsibility for conduct of requisite training and handholding sessions on working and operation of AMR for the Nigam staff so that the operation can successfully be transferred to DHBVN after completion of the one year operational period of the supplier.

1.4 During the operation period of one year post successful roll-out of AMR system, the supplier would carry out various activities like generation of periodic MIS reports as required, updation of the database with respect to new consumers etc.

Maintenance of AMR system

1.5 The implementation agency shall maintain the AMR system for a period of 5 years from the date of successful installation and commissioning of the AMR system.

1.6 The maintenance contract to be signed with the IA post award of work would include the following

(a) Performing periodic checks on sample field meters, concentrators and other associated field infrastructure; in case of foreign bidders, they should either camp their own maintenance team at the project site or engage the local contractors to ensure that the operation and maintenance activities are handled all the time in an efficient manner



(b) Periodic testing and necessary upgrading of the BCS software and hardware;

(c) Timely responding and attending to various operational queries and troubleshooting of teething problems and system malfunctioning;

1.7 The periodicity of checks and timelines shall be finalized with the supplier before initiating the project.

Scope regarding Communication Services

1.8 The Supplier shall be responsible for providing the communication services between the meters and the Data Center.

1.9 The contractor shall supply each link provided across the communication path.

1.10 The installation and configuration of the routers or any other communication equipment(s) shall be the sole responsibility of the SUPPLIER;

1.11 All the equipments required to be installed at the consumer’s premises shall be installed inside Meter Box. In case the Meter box is required to be changed, the supplier shall be responsible for bearing all cost of installation/replacement of meter box. Meter box shall be used of appropriate size and latest specifications with proper degree of protection from weather & external conditions to which the LV metering system would remain exposed.

1.12 All equipments that will be installed across the communication path (from meter to Data Center), such as routers, modems and interface converters shall be installed by the supplier in a secure way and he shall be responsible for all cost associated with the installation.

1.13 The Communication Infrastructure must be scalable, assuring the features required in the Specification, for the expansion of the remote points. The Meter Reading System shall ensure the scalability to meet up with all utility low consumption customers. The Supplier must indicate the additional costs for the utility for full deployment of the solution.

1.14 Adaptation to topology changes has to be supported by proposed solution by the supplier. Since the Electric power and communication network are not static, as such the protocol or the system have to provide the routing function adapted to network changes.

1.15 Communication function with meters needs to support a fully automated repetition procedure following always the optimal communication path.



1.16 Communication function is required to offer information on online quality such as signal/noise ratio, attenuation and data loss statistics for all its components.

Approach for Implementation

1.17 It is pertinent to mention that owing to the high set-up cost, risks associated with new technology and to get a first-hand experience of AMR, it has been decided that the proposed AMR shall be first implemented on Pilot basis in one sub-division in a circle (Exact locational details shall be intimated subsequently after allotment of work) for 50 connections including DTs.

1.18 The pilot implementation time would be 2 months from the date of award of contract. One month period is allocated to the supplier for getting the requisite conformance certifications for Indian conditions from accredited laboratories.

1.19 The pilot sub-division will be such that the implementation of AMR of 50 connections & DTs is closely monitored for all the applicable categories of consumers and the learning and experiences, from the pilot, can be taken and incorporated during the full roll-out of the AMR. The evaluation of the pilot will be done for a period of 1 month to give sufficient time to the supplier for cover-up of initial blocades that may occur in implementation of a new technology.

1.20 Based on the success of the pilot project, a go-ahead shall be given to the firm for complete roll-out of the AMR project for the envisaged categories of consumers & DTs in entire operational jurisdiction of DHBVN.

During 1 month period of running of pilot project, the supplier will be responsible for operating the AMR system on day-to day basis. However, the supplier will carry out the operations of BCS in presence of DHBVN staff and under the directions of Nigam viz. the supplier will furnish MIS reports as desired by DHBVN and assist in resolving related consumer complaints. After the completion of pilot phase, if it is observed that the pilot project does not match up to the functional specifications and benchmarks set by the employer then in that case DHBVN has the right to terminate the contract.



Circle Wise DTs, HT and LT Connections, which are to be covered in this project:-

Sr. No

Name of Circles

DT Connections

HT Connections

LT-CT Connections

Poly-phase Connections

Total Connections

1 Hisar 356 405 1409 5257 7427 2 Sirsa 169 45 564 2815 3593 3 Faridabad 200 1580 7400 17449 26629 4 Gurgaon 919 1586 5990 32355 40850 5 Bhiwani 56 265 569 2044 2934 6 Narnaul 152 57 209 1402 1820 7 Rewari 0 284 419 1611 2314 Total 1852 4222 16560 62933 85567

• 1500 meters on HT Connections are equipped with DLMS Compliance Meters, hence not

required to replace. However the remaining meters shall be replaced with DLMS compliant meters (without meter boxes).

• 4000 meters on LT Connections are DLMS Compliant Meters, hence are not required to be

replaced. However the remaining meters shall be replaced with DLMS Compliant. (Without meter boxes).

Tentative High Level Diagram of the AMR System shall be as follows.



Section 3: Pre-Qualifying Requirements

1. Nationality – Nationality should be in accordance with ITB 4.1

Pre-Qualifying Requirements

Single Entity

Joint Venture, Consortium or Association

All Partners Combined

Consortium Partners (Other than Partner-in-

Charge)

Partner In-Charge

(Lead partner)

Documentation Required

Must meet requirement

Existing or Intended JVA must meet requirement

Must meet requirement N/A

Form ELI-1.1and1.2,

With attachments

2. Conflict of Interest - No- conflicts of interests as described in ITB 4.3

Single Entity




Charge)

Partner In-Charge

(Lead partner)



Existing or Intended JVA must meet requirement


Must Meet Requirement

Letter of Bid

3. Bank Ineligibility - Not having been declared ineligible by the Bank as described in ITB 4.4

Single Entity



Consortium Partners

(Other than Partner-in-

Charge)

Partner In-Charge (Lead

partner)



Existing or intended JVA

must meet requirement



Letter of Bid



4. Government Owned Entity - Compliance with conditions of ITB 4.2 (c)

Single Entity



Consortium Partners


Charge)


partner)




must meet requirement



Form ELI-1.1and1.2, With attachments

5. Ineligibility based on a United Nations resolution or Borrower’s country law - Not having been

excluded as a result of the Borrower’s country laws or official regulations, or by an act of compliance with UN Security Council resolution, in accordance with ITB 4.2 (a)

Single Entity



Consortium Partners


Charge)

Partner In-Charge (Lead partner)




must meet Requirement

Must Meet requirement


Letter of Bid

6. History of non-performing contracts - Non-performance of a contract may not have occurred

during last five (5) years prior to the deadline for application submission, based on all information on fully settled disputes or litigation. A fully settled dispute or litigation is one that has been resolved in accordance with the Dispute Resolution Mechanism under the respective contract, and where all appeal ptions available to the bidder have been exhausted.

Single Entity

Joint Venture, Consortium or Association All

Partners

Combined


Charge)


partner)


Must meet Requirement by itself or as partner to past or existing JVA

N/A


Must meet requirement by

itself or as partner to past

or existing JVA

Form Con-2



7. Pending Litigation - The bidder should submit an affidavit or self-certificate, duly attested by statutory auditors that all pending litigation of the firm does not represent more than Fifty percent (50%) of its net worth.

Single Entity


Partners

Combined


Charge)


partner)



N/A


Must meet requirement by

itself or as partner to past

or existing JVA

Form Con-2

8. Historical Financial Performance - Submission of audited balance Sheets or if not required by

the law of the bidder's country, other financial statements acceptable to the Employer of the last Three [3] years to demonstrate the current soundness of the bidder’s financial position and its prospective long term profitability.

Single Entity


Partners

Combined


Charge)


partner)


Must meet Requirement N/A Must meet

Requirement Must meet

Requirement

Form FIN–3.1with attachments

9. Average Annual Turnover – Bidder shall have minimum average annual turnover of $15million in last 3 years.

Single Entity


All Partners Combine

d

Each Consortium Partners (Other than Partner-in-

Charge)



Must meet Requirement N/A

Minimum average annual turnover of

US$5million in last 3years

Minimum average annual turnover of US$ 10 million in

last 3years




10. Financial Resources and liquidity position –The bidder must demonstrate access to, or availability of financial resources such as liquid assets, unencumbered real assets, lines of credit and other financial means, other than any contractual advance payments to meet minimum net cash flow requirements of US$15million.The liquidity position of the bidder/ lead member of the consortium should be equal to or greater than one for the last 3 financial years. Liquidity position is to be assessed based on the bidder's liquid assets and current liabilities for the last3 years.

Single Entity


All Partners Combine

d


Charge)



Must meet Requirement N/A

Must meet Thirty Percent(30%)of the requirement

Must meet Seventy Percent(70%)of the requirement


11. General Experience - Experience under contracts in the role of contractor, management contractor

or subcontractor for at least 7 years with prior experience in field of a. Electricity meter supply & installation, b. IT infrastructure setup and operation and maintenance of the Data Management System.

Single Entity




Charge)


partner)


Must meet Requirement


for all characteristics

Must meet Requirement not met by the lead

partner

Must meet requirement for at

least one characteristic i.e.

either a or b

Form EXP 1.4.1

12. Specific Experience - The bidder must provide evidence of prior experience in the supply, installation, commissioning and operation and maintenance of Automated Meter Reading (AMR) systems for electricity distribution companies, as per details noted below: a. Experience (own or through sub-contractors) in the installation at customers' premises and



commissioning of at least 40,000 meters and communication devices of AMR systems with the same functionalities of the equipments in the technical proposal in last 5 years.

Proof of Experience-Completion Certificate on Client letter-head (System should be running successfully for the last six months at least).

b. Own experience in the supply, installation, commissioning and operation for at least one year of

MDAS Software with the same functionalities of the MDAS included in the technical proposal and managing 40,000 or more points of supply installed at consumer premises in last 5 years.

Proof of Experience-Completion Certificate on Client letter-head (System should be running successfully for the six last months at-least).

Single Entity




Charge)


partner)


Must meet Requirement


for all characteristics

Must meet Requirement not met by the lead

partner

Must meet requirement for at

least one characteristic i.e.

either a or b

FormEXP 1.4.2

Mandatory Requirements

S. No. Requirement Support Document / Validation Proof

1 Meter Manufacturer OEM must possess valid ISO 9001:2008 certification for meter manufacturing, & ISO 14001:2004 for environmental management system

Certificates

2 Meter Manufacturer OEM must have aggregate annual turnover of minimum Rs. 400 Crores (or US$ 80 million) in the last three financial years in respect of metering business only.

Financial Statements of last three financial Years. These documents shall be

duly authenticated by registered CA




3

Meter Manufacturer OEM must have manufactured and supplied minimum quantity of Five (5)Lacs, any type & rating of fully static energy meters with LCD display & communication port during the last three financial years including 50,000 DLMS meters of any rating.

LoI/Work Order/ Completion Certificate

4 The Mete Manufacturer OEM should not have been blacklisted by any utility in India. Self-Certificate

5

The Meter Manufacturer OEM must possess a valid Bureau of Indian Standard Certification (ISI mark) for meters being manufactured in India/ Equivalent International Standards for Foreign bidders.

Certificate

6

One no LT accucheck equipment of accuracy class 0.2 in case of direct mode & 0.5 class in case of clamp-on CT mode with current range of 100A usable for single phase as well as three phase meters, with every 5000 ( Five Thousand ) meters shall be supplied free of cost as per the specifications enclosed in the tender.

Self-Certificate

7

Meter manufacturer OEM shall submit a copy of valid certificate of Capability Maturity Model Integration (CMMI) version 1.3(or above) issued by recognized body like SEI etc. along with his technical bid

Certificate

8

AMR system should be inter-operable among different makes of meters. For this objective to achieve, bidder shall consider at-least two different makes of Meters for this project with at-least 25% of meters from each manufacturer.

Self-Certificate in the technical proposal with

meter makes, model, version and quantities

9 The Meter Data Acquisition Software shall be based on Web based architecture

Self-Certificate and Document

10 The solution shall be designed with Open Industry Standards and not with Supplier’s Proprietary Protocol. Self-Certificate

11 The solution shall be designed with Service Oriented Architecture Self-Certificate




12 The MDAS application shall provide the functionality to configure the parameters to define the business rules with the application. These parameters shall not be hard-coded in the application.

Self-Certificate, Document

13 The solution shall provide the functionality to maintain the audit trail of all critical transactions.

Self-Certificate

14

The solution shall be able to interoperate with:

• standard RDBMS platforms like Oracle, MS SQL, MY SQL, DB2, Informix, Sybase or any other RDBMS conforming to ANSI/ISO SQL-200n

• Standards operating systems like Windows, UNIX, and

Solarisetc.

• Web browsers like Internet explorer, Mozilla Firefox, Opera etc.

Self-Certificate and Document

15

The O&M cost for five years shall be minimum 20% of the total project cost (excluding O&M and bandwidth cost) failing which the bid shall be declared as non-responsive. The bidder shall give self-declaration that the O&M Cost has been taken as minimum 20% of the total project cost (excluding O&M and bandwidth cost) and if it is less than 20%, its bid may be declared as non-responsive.

Self-Certificate in the Technical Proposal.

16 Bidder shall provide the basis details of sizing of servers, storage and network bandwidth in the technical proposal. Document

17

The Meter data acquisition Solution shall be capable of collecting and analyzing data on a common data structure/ format from system/ consumer’s meters of various makes and models.

The solution shall be compatible with present Modbus compliant meters installed in utilities as well as future meters likely to be introduced in Indian market complying with DLMS

Self-Certificate by the Bidders




/COSEM/IEC-62056/ANSI C-12.19/IEEE P-1377 Standards.

18 The software version shall be supported by the software vendor for a minimum period of next five years


19 The solution shall be horizontally and vertically scalable and also have virtualization capabilities.


20 MDAS software must comply in entirety with of the technical specifications mentioned in the tender document.

Technical Specifications Sheet with Self-Certificate by the Bidders

21

The Bidder should have at least10 personnel on its rolls with minimum experience of 5 years (either in his/her own or other organization). The roles & responsibilities of the personnel should include Metering (Installation, Testing,) or AMR or AMI or Networking or IT Infrastructure. In case of a consortium, the requirement of at least10 personnel is distributed as follows: -Partner-in charge needs to meet the above requirement for at least 6 CVs, -Consortium partner needs to meet the above requirement foratleast 4 CVs.

Proof: Signed resume of employees need to be submitted. Scanned signatures shall be accepted.

22

The bidders or Partner-in charge must possess certification for ISO 9001:2008, OHSAS 18001:2007, ISO 27001:2005 and CMMI Level-3 or above. All other consortium partners shall possess ISO 9001:2008.

Valid Certificate

Note-The bidder(s) should provide valid certificates, test reports and other credentials on the date of bid submission.



Section 5: Bid Features

The System will be implemented in accordance with the relevant standards. Under circumstances of continuous development of technologies and accompanying standards, it must be ensured that the proposed solution has been aligned with the latest developments in this field. Basic part of the material includes technical and functional specification. The task of introductory texts is to explain more closely the objectives, principles, context, requirements, approach to system implementation and other aspects having an impact on the contents of the technical specification.

The most important implementation objective of AMR System is the Revenue Protection. Besides it, the following benefits shall also accrue:-

• Increase of metering accuracy and reduction of the number of complaints; • Reduction of reading costs and increase in the number of read electricity meters; • Acceleration of invoice issuing and reduction of collection period; • Reduction of non-technical losses; • Implementation of technological platform for application of complex tariff system;

The System must also have the capability to implement advance applications viz Load Control, Load Analysis, Outage Monitoring and Detection of Tampering. The System is based on the following principles:

• Interoperability • Reliability; • Scalability; • Flexibility; • Modularity; • Data security

1. If bidder intends to make non-material deviations against from the terms & conditions

of the tender, it should be mentioned specifically in the deviation sheet. Unless such deviations are mentioned in this deviation sheet, the same will not be taken into consideration.



2. Compliance to Hardware components specifications is the minimum requirement (and hence mandatory) for the Utility and needs to be supplied as per the given or higher specifications. In case the bidder decides to make any deviation, the same has to be clearly mentioned in the deviations sheet. Utility shall decide if the same is acceptable or not. In case the same is not acceptable, the bid shall be rejected and financial bid of the bidder shall not be opened.

3. Selected Bidder shall set up Project Management Office at Hisar, Haryana within 30

days from the date of Agreement. This office shall remain operational till the successful completion of this project i.e. Implementation stage (18 Months) and O&M Stage (60 Months). All the dedicated resources are to be deployed at Hisar for day-to-day coordination with Utility.

4. Assignment: - The appointed Implementing Agency shall not assign, in whole or in part its

obligations to perform under this contract, without prior written consent of DHBVN.

5. Whenever a metering unit or meter gets defective or is replaced due to any reason, it is the responsibility of the AMR Implementing Agency to facilitate such changes at the consumer premises. The appointed Implementing Agency shall be required to deploy at least one technical person with a vehicle, tools and plant at each of the 7 circle H/Qs for maintenance / replacement of defective metering/modem equipments etc. The Implementing Agency is also required to keep a provision of 10 % items deployed as capital spares and maintain prescribed inventory level as a percentage of installed equipments in the circle. Circle-wise level of inventory to be maintained shall be notified to the Implementing Agency subsequent to the placement of order. The site store of the Implementing Agency shall be verified at the end of every month by the concerned EE (Division Office) certifying the level of minimum inventory, as specified. The Implementing Agency is required to replace the defective meter/Modem or any other equipment etc. within 48 hours of its failure and submit a monthly breakdown report to the concerned EE (Division Office).

6. The data downloaded through proposed AMR system should match completely with the data

available in the meter downloaded through Meter Reading Instrument. This will be a mandatory requirement for acceptance of AMR system during pilot phase.

7. Proposed AMR System should have provision to upload the meter data, which is downloaded

through Meter reading Instruments.

8. The bidder needs to warrant that the AMR Modems will be new, unused and in accordance with the technical specifications and free from defects in material and workmanship. The modems shall be guaranteed for satisfactory performance for a period of 5 years from the date of installation.



9. Return of dismantled material :- The contractor shall take custody of all dismantled material from site and shall remain responsible for the same till the material is returned to Nigam stores through Nigam’s concerned supervisory officials. The contractor shall also maintain record of all such dismantled material removed from the sites and returned to stores.

10. Guarantee/Warrantee Support:- Bidders should provide guaranteed services for all equipments licenses & allied activities for a period of 5 years from the date of start of O&M Phase unless otherwise specified. All Hardware equipments or its components in guarantee/Warranty period shall be changed in case of any observance of failure and software components shall be modified / replaced to ensure trouble-free operation of the system.

11. Project Management and Site Supervision

a. The bidder shall be responsible for the overall management and supervision of works.

He shall provide experienced, skilled, knowledgeable and competent personnel for all phases of the project, so as to provide the Owner with a high quality system. Bidder should provide details of the proposed project structure identifying key individuals, e.g., Project Managers and their roles, including the number and location of proposed analysis/development personnel. Due to the expected impact on the business processes, it is extremely important that owner should obtain a thorough understanding of the organization and individuals proposed for the project and the roles Owner’s staff would be expected to play.

b. Bidder should also provide details of sub-bidders likely to be involved indicating the number of full time corresponding personnel that would be required from DHBVN’s side. Resumes or personal profiles should be provided for key personnel of his organization for the project.

c. The bidder is expected to provide estimate of the required number of DHBVN’s

personnel and to identify the skills required. It shall provide details for the following:-

i. Number of Full Time corresponding personnel (separate IT and Business) required throughout the duration of the project.

ii. Key roles to be included from the business. iii. Key roles to be included from Metering and AMR.

d. Bidder should provide details of governance roles including

i. Steering Committee ii. Number and Frequency



12. Documentation Scope

a. Sufficient sets of following documents should be provided to the utility for referential, record, monitoring and supervision purposes:- • User Manuals • System Administrator Manuals • Technical Manuals • Installation Guides • Business Process Guides • Program Flow Descriptions • Sample Reports • Screen Formats • Toolkit Guides • Troubleshooting Guides • Frequently Asked Question (FAQ) Guides

b. The bidder should ensure clarity, comprehensiveness and accuracy of the documentation.

c. Hard copy and soft copy of user manuals are expected to be provided by the successful vendor. These documents should include information on the application concepts and should also consist of transaction and field level documentation. Additionally, the Technical Users Information manual provides information on the BPA software’s table structures.

d. Selected Bidder will be expected to assist in developing operational procedure

manuals. If the user manuals are provided in Word format, the client should have the ability to customize their own manual to include specific business processes or operational procedures.

e. Selected Bidder may also be required to provide relevant and emergent on-line help,

which includes all materials provided in the hard copy manuals. Wherein possible, users should be able to add their own on-line help documentation.

13. Data Security: - The software should have necessary features to maintain audit trails with complete event logging and internal check system to prevent fraud and manipulation of data. The software shall have multi-level configurable password control for data protection, integrity and security of the system. The different software features shall be protected by



different passwords. All configurations of User Management / Access Rights shall be as per the requirements of DHBVN.

14. The Disaster Recovery Center (DRC) will be an exact replica of Data Center i.e. all the

software, hardware and network equipments and other items etc. provided at Data Center will also be installed and commissioned at Disaster Recovery Center along with relevant licenses to support all operations from DRC during DR drill and in event of disaster. DC is planned at Hisar and DRC is tentatively planned at Panchkula. DRC location shall be finalized with selected bidder during implementation.

15. Each of the AMR database servers shall be enterprise level SMP RISC / EPIC / CISC / x-86,

64- Bit processor based system and should be capable of minimum TPM-C rating of 14,00,000 (14 Lacs) or higher for fully populated configuration. OEM should certify this on its letterhead with the estimated benchmark.

16. The bidder shall provide enterprise wide license without constraint of number of CPUs / Core

/ Number of Users / Number of Consumers for AMR/MDAS Application.

17. Training for the DHBVN’s Employees

a. The vendor shall be required to organize following training for the owner’s personnel:- • Professional Training - This training is intended for the core Group of

implementation team of the owner. This team will comprise of members from all the Business Functions and IT. Each member would be trained in the relevant function / module. This Training would be required to be given to approximately 15-20 personnel of DHBVN. It is the responsibility of lead partner to deliver this training. Standard curriculum designed and agreed by the owner for hardware, software and network system who shall arrange the training for each group preferably from the OEM partner or OEM’s certified training partner. The vendor is required to quote training charges on per person basis. The Purchaser will prefer if part of this training is conducted on-site.

• End User Training - The bidder will provide training to owner’s team on a "Train the Trainer" basis. The Owner’s team so trained will then train all of the owner’s end users. It is estimated that this training schedule will require involvement of about 14-15 groups (i.e. two groups per circle), with each group comprising of 15



to 20 persons. These training sessions will be required to be conducted at any of the sites.

• The recommended training material can be in paper / electronic modes with

courses on BPA software fundamentals, business process overview, job activity training, and delivery options being on-line, CBTs, instructor led class rooms, etc.

• During the course of the implementation, the bidder is expected to complete / be

involved in the following activities in terms of skill transfer :-

o Testing scripts should be prepared to test the business processes and scenarios of the new system.

o The project team members will further develop these testing scripts into training documents.

o Training material will be organized by functional process that will serve as

the training documentation for a particular functional area.

o Assist the Owner’s team members in creating procedure documents for use in conjunction with the other training material. A procedure document will list all of the transactions necessary to complete a business scenario whereas a training document lists the steps to execute a transaction. Each step will be a transaction referenced in a training document. Procedures will be listed for all the online steps needed to complete a scenario.

o In addition to functional training document binders and procedures, the

project team members will create training courses and exercises. The training courses will contain all the training documents and necessary to train an end-user in his / her role. The training exercises will list common business scenarios and input data that the user will enter to practice with the newly developed BPA software.

o Vendor will assist in administering training to project team members and /

or power users, to “train the trainers”.

o Vendor should assist in administering training to the rest of the users / peers in functional areas based on the course documentation developed by the project team and vendor.



• The training will consist of a curriculum of courses to address the issues of system

operation, business-wide application, changed business processes and the general use of the new system.

• Representatives from the successful vendor, utility’s implementation project and

change management teams will be involved throughout in the development of training strategy, training material design and development, standards and training delivery to ensure that change management issues are incorporated, and that training strategies and materials are aligned to the requirements of the project and should also be as business-specific as possible.

• The roll-out of the training program will be coordinated with the overall project

implementation strategy.

18. Integration Scope

a. The scope of integration of external systems includes IT systems already existing and are functional internal to the utility, but outside the present scope of work. The integration is expected to be on-line real time or batch basis wherever appropriate and shall operate in an automated fashion without manual intervention. The scope of external integration will be, but not limited to :

i. Selected agency shall make all possible arrangement to facilitate for End to End Integration with R-APDRP (Part-A) Applications. Few key requirements of Data-Sharing with R-APDRP (Part-A) are as follows, but not limited to

1. Data will be exchanged via MIOS based XML

2. Complete responsibility of designing the new system so as to

seamlessly integrate with the R-APDRP system would lie with the bidder. For ensuring the same the bidder will have to conduct a comprehensive study of the present system and propose integration options accordingly, the most appropriate option will be selected and the bidder is expected to quote accordingly.

ii. Sub-Division Automation System of DHBVN for Metering, Billing and Collection being used in 13 sub-divisions.

iii. Billing Systems being utilized at Circle offices



iv. Utility Web Portal v. Stand-alone existing applications

vi. SAP-ERP vii. Transactional as well as standing or master data to and from the offered

system will be required to be interfaced. viii. Data to be integrated must be validated by the developed interfaces.

ix. All interfaces should have self- checking feature so that any exceptions or data validation errors are reported by the system. In addition, integration logs should be maintained that confirm the success or failure of the interface, complete with control tools.

x. The mapping should be manageable through a GUI based administrative interface.

xi. Future applications like SCADA, Pre-Paid, OMS, AMI, Smart-Grid etc.

19. Selected Agency will be responsible for making all possible arrangement to facilitate for End to end integration with all new applications (wherever integration with AMR system is required) that will be commissioned by DHBVN during the contract period (i.e. 78 months from Contract date).

20. Data Migration Scope

a. All required data shall be migrated from utility’s legacy systems as per requirement.

Data to be migrated will be cleansed, rationalized, transformed (if required) and reconciled. Conversion programs may be required to be written to handle this task.

b. The total data migration scope will be finalized by the owner with successful bidder. The following is the indicative list of the type of data to be migrated from the legacy/ manual system.

i. All Master Data – Must be migrated

ii. All Open Transactions – Must be migrated iii. All transactions in the current financial year – Must be migrated. iv. Historical Transactions – No of years shall be decided by utility, however, at

least 3 years historical data to be migrated.

21. MIS formats will be as per the prevailing formats of the DHBVN. The vendor needs to incorporate all changes in MIS applications required by Discom during the implementation phase. All the requirements of MIS will be finalized with selected bidder during the system designing phase.



22. Quantity Variation :-

a. The quantities of meters, modems and other items mentioned in the tender document

are tentative. The DHBVN reserves the right to increase or decrease the quantity of goods/ services specified in the Price & Quantity Schedule based on actual requirement at the time of award of contract / at the time of execution of work without any change in price or other terms and conditions. Therefore, inter-item adjustment is not allowed. Tenderers are advised that prices of an item should not be adjusted in the prices of others in the price bid. Price of each item should be quoted on its own because quantity of any item may increase or decrease at the time of award/execution of work and, in such a case, unit price of each item will be the basis of the payment.

23. Manual Reading :- Wherever, meter reading can-not be done due to communication failure

or fault at modem/meter/MDAS software level continuously for 48 hours , for all such cases, Implementing Agency shall download the data from all these meters using CMRI machines on weekly basis. CMRI machines shall be arranged by Implementing Agency. Downloaded data of these meters are to be uploaded in the MDAS system by Implementing Agency within 24 hours from the date of downloading of data. At any point of time, manual data downloading through CMRI/MRI should not exceed 5% of the meters under AMR Project.

24. Arrangement by the Contractor

a. The bidder shall make his own necessary arrangements for the following facilities and for those activities/ facilities not listed anywhere else

i. Office and Store ii. Transportation

iii. Boarding and Lodging arrangement for their personnel.

b. The bidder shall also provide all the construction equipments, tools, tackles and testing kits/equipments required for pre-assembly, erection/installation, testing and commissioning of the equipments and system covered under the Contract. He shall submit a list of all such materials to the Engineer before the commencement of work at Site. These tools and tackles shall not be removed from the Site without the written permission of the Engineer-in-charge.

c. All material accessoriesrequired for complete installation such as Lugs, Mounting Clamps, screws, wires, cables, connectors, as required for installation and commissioning of the modems shall be arranged by the Contractor.



d. Single core LT PVC un-armoured cable of appropriate size and length commensurate with the capacity of DT shall be erected at the DT meter installation sites.

25. The Bidder shall be responsible for providing all material, equipment and services specified

or otherwise, which are required to fulfill the intent of ensuring operability, maintainability and the reliability of the complete work covered under this project.

26. It is not the intent to specify all aspects of design and installation of associated systems mentioned herein. The systems, sub-systems and equipments/devices shall conform in all respect to high standards of engineering, design and workmanship, and shall be capable of performing continuous commercial operation.

27. Whenever a material item or an article is specified or described by the name of a

particular brand, manufacturer or trade mark, the specific item shall be understood to be of established type, function and quality desired. Products of other manufacturers may also be considered, provided adequate information is furnished so as to enable the owner to determine that the products are equivalent to those named.

28. Bidder is requested to carefully examine and understand the project and seek clarifications, if

required, to ensure that they have understood the specifications. Pre bid conference shall be held by utility to offer any clarifications against the queries raised by the various vendors, who have purchased the bid documents, to remove any doubts of the bidder and to remove any ambiguity in document. The procedure for organizing pre bid conference has been described in detail in “Section-ITB” of the Contract document. The bid from bidder should not include any sections like clarifications, interpretations and/or assumptions.

29. Any deviation or variation from the scope requirement and/or intent of this specification shall

be clearly mentioned under Deviation Schedule of the Bid Proposal Sheets irrespective of the fact that such deviations/variations may be standard practice or a possible interpretation of the specification by the Bidder. Except for the deviations/variations that are accepted by the Owner with or without financial implications before the award of the contract, it will be the responsibility of the Bidder to fully meet the intent and the requirements of the specification within the quoted price. No other departure from the specifications except for the declared deviation(s) indicated by the Bidder in his proposal shall be considered. Bids not complying with this requirement shall be treated as non-responsive and hence shall be liable for rejection. The interpretation of the Owner in respect of the scope, details and services to be performed by the Bidder shall be binding, unless specifically clarified otherwise by the Owner in writing before the award of contract.



30. The Bidder shall be responsible for detailed design and engineering of overall system, subsystems, elements, system facilities, equipments, services, including systems application software etc. It shall include proper definition and execution of all interfaces with systems, equipments, material and services of Owner for proper and correct design, performance and operation of the project. Bidder shall provide complete engineering data, drawings, reports, manuals and services offered etc. for Owner’s review, approval and records

31. The Bidder shall also be responsible for manufacture, inspection at manufacturer’s works,

supply, transportation, insurance, delivery at site, unloading, storage, complete supervision, installation and successful commissioning of all the equipment, systems and application software listed as BoM(Bill of Material) in this project.

32. Any item though not specifically mentioned, but is required to complete the project work for

its safe, reliable, efficient and trouble free operation, shall also be deemed to be included, and the same shall be supplied and installed by the Bidder without any extra cost.

33. The bidder’s proposal shall include the list of special tools, testing equipments and

accessories required during development stage, for day- to- day operation and maintenance of the system. All such tools shall be supplied by the bidder. The bidder should clearly bring out the list of such tools along with itemized price in the bid. However the prices of these special tools shall be included in the lump sum bid price and would be considered for the bid evaluation.

34. Annual Technical Support

a. The Bidder shall provide support and maintenance of all the software supplied as solution to the utility for a period of five years from the date of installation of the relevant number of licenses of the software. This support shall be provided by trained and experienced personnel of the bidder. During this period, bidder shall be responsible for carrying out the following activities.

i. Provide free patches/ hotfixes/ updates/ upgrades/ notes etc. for Operating Systems, Databases or any security upgrade of the products to the utility as and when released by OEM.

ii. SLA Based Support through telephone/Fax/E-mail/ personal visit.



35. System Availability

a. System reliability will more often be dependent on hardware, database, and communications availability. The vendor will need to clarify whether they require or intend to impose any particular hardware and database management techniques or other requirements. The AMR system availability (both software and hardware combined) shall not be less than 99% at data center calculated quarterly.

36. Software Tools

a. Software tools must be latest versions that are currently supported by manufacturer, if relevant. Software tools must be compliant with generally accepted standards and accommodate Utility’s plan for the future expansion of systems. Utility also expects tools and automation to feature in the implementation so as to maximize the efficiency and quality of the AMR project.

37. Spares

a. The Bidder shall include in his scope of supply all mandatory and commissioning spares related to Hardware requirements. The bidder has to quote for the mandatory spares requirement for 5years operation after warranty period. List of such spares along with the quantities shall be indicated in the bid and shall be considered for bid evaluation purpose. All spares supplied under this contract shall be strictly interchangeable with the parts intended for replacement. The spares shall be treated and packed for long-term storage in the climatic conditions prevailing at the project site. Small items shall be packed in sealed transparent plastic covers with desiccant bags as necessary. The bidders shall attach the storage conditions requesting covered storage or storage under air conditioned environment as appropriate for certain classes of spares.

b. Each spare part shall be clearly marked and labeled on the outside of the packing

together with the description when more than one spare part is packed in single case. A general description of the contents shall be shown outside of the case and detailed list enclosed. All cases, containers and other packages must be suitably marked and numbered for the purpose of identification.

c. The Bidder shall supply spares, which he expects to consume during installation,

testing and commissioning of the system. The quantity of these spares shall be decided based on his previous experience, such that site works shall not be hampered due to non-availability of these spares. Bidder shall submit a complete list of such



spares along with the bid, the cost of which shall be deemed to have been included in the lump sum proposal price of the package. The unused commissioning spares may be left at the site for use by the Owner, if so agreed at a cost to be negotiated.

d. No spares except commissioning spares will be used during the commissioning of the

system before take-over by the Owner. In case of extreme urgency, if spares other than commissioning spares are used by bidder for commissioning of the system, the same will be required to be recouped free of charges.

38. Risk Management

a. The vendor will also be expected to work with DHBVN project manager to regularly review and amend the list of risks and their mitigation strategies. Risk could emerge as per the details noted below ( but are not limited thereto only) :-

i. Meter Data Read related issues

ii. Communication Network Performance iii. Availability of Vendors iv. Inadequate participation by Utility Staff v. Information required for the project is not being provided as per planned

timeframes vi. Not meeting Utility’s expectations in terms of scope, timing and quality.

vii. Project scope creep. viii. Lack of project ownership.

ix. Availability of internal and external resources. x. Not signing off project deliverables and providing project acceptance in a

timely fashion xi. Logistic Delays

39. Testing, Commission and Successful Operation

a. The scope includes testing and commissioning & implementation of all equipments, sub-systems and systems of the project and transforming them into successful technical & commercial operation. The scope shall include but not limited to the requirements given elsewhere in the specification. The bidder shall be responsible to provide all necessary testing and commissioning personnel, tools/kits, test equipments etc.

40. Testing and Acceptance Procedures

a. Testing and quality assurance in software development is more rigorous since each component has to be more reliable, if it is to be reused. A system is tested at various



stages of development and deployment. For example, each component is tested as a unit for checking the correctness of its own code. Further, the component is tested with its dependent components. After final release of the entire set of components, system is tested for the correctness of system functionality. Finally the components are further tested in simulated production load for performance and load analysis.

b. The Lead Partner along with consortium partners shall be responsible for the testing processes such as planning (includes preparing test plans and defining roles and their responsibilities), preparation (consists of preparing test specifications, test environment and test data) and execution (includes testing at various levels like unit level, integration level, system level and production).

41. Test Plan

a. Test plans are prepared for each phase of testing. The initial test plan is created during

the Project Planning phase. The initial test plan describes who performs which type of testing and when. Ideally master test plan covers all types of tests i.e. from unit testing to production testing. The Lead Partner along with consortium partners is expected to submit the test plans to Utility for approval. Any changes made to the test plan during the project life cycle should be communicated to utility for approval.

42. Test Scenarios

a. The Lead Partner along with consortium partners should prepare test scenario for each business scenario. A test scenario when executed should fulfill a business requirement as per the scope of business functionality. Test scenarios include following :-

i. Test Specification - During the test specification phase, the test cases are specified. It consists of description of the input, process to be executed and a prediction of output results.

ii. Test Environment - Component developer does unit testing and integration testing. Integration testing can be delegated to a specialized testing group. Each of the members in the testing group is provided with testing environment according to his/her role and responsibilities. Following is sample testing environment for testing:



1. A Workstation 2. A set of tools and applications required on workstation like access to

user interface, browser etc. 3. Access to centralized document database (where all the project related

documents are maintained). 4. Access to testing tools and defect logging tools. 5. Access to the central database or repository for development and unit

testing (this database contains sample test data). 6. Access to deployed components.

iii. Test Data - Test data is prepared for testing at each stage. The test data should

be prepared in such a way that it covers basic path and every alternate path of the code. The basic path and alternate paths are prioritized to capture relevant data. Tools can also be used to generate test data.

43. Test Execution The following testing steps are usually employed in the project lifecycle. The Lead Partner along with consortium partners are expected to follow these steps:-

a. Unit Testing - In unit testing, each piece of code has to be rigorously tested. At this stage testing is done according to the priority of path of code. All the test results are logged in the defect logging tools. After every completion of unit testing, code is corrected for defect logs. This process is iterative till criteria for successful testing is reached.

b. Integration Testing - Upon completion of unit testing, integration testing begins. The purpose is to ensure distinct components of the application still work in accordance to customer requirements. Test sets will be developed with the express purpose of exercising the interfaces between the components. This activity is to be carried out by the Test Team. Integration test will be termed complete when actual results and expected results are either in line or differences are explainable/acceptable based on client input.

c. Incremental Integration Testing - Continuous testing of an application as new

functionality is added. d. System Testing - System testing is performed when all the components are delivered

to central repository prior to the release of the software. The testing is done on



priority basis of business processes. All the defects are logged and assigned to respective component owners. The component and unit testing is performed after the correction of code. However, it may depend on size and type of individual test specifications. Impact analysis is useful to narrow down testing efforts by identifying critical test cases affected due to code change.

e. Pre-Production Testing – Pre-Production testing is done simulating the production

load. Test data is either prepared or generated from the tools. This testing is used to evaluate performance, load capacity and concurrency. Load testing tools can also be used for this purpose. Following special type of testing is done during Pre-production Testing Phase:

i. Regression Testing - The objective of regression testing is to ensure the

sustainability of software. A baseline set of data and scripts will be maintained and executed to verify changes introduced during the release to ensure that the charges ( introduced) have not “undone” any previous code. Expected results from the baseline are compared to results of the software being regression tested. All discrepancies will be highlighted and accounted for, before testing proceeds to the next level.

ii. Performance Testing - Although performance testing is described as a part of system testing, it can be regarded as a distinct level of testing. Performance testing will verify the load, volume, and response times as defined by requirements.

iii. Load Testing – It involves testing an application under heavy loads, such as

the testing of a web site under a range of loads to determine at what point the systems response time degrades or fails.

iv. Installation Testing – It involves testing full, partial, or upgrade,

install/uninstall processes. The installation test for a release will be conducted with the objective of demonstrating production readiness. This test is conducted after the application has been migrated to the client’s site. It will encompass the inventory of configuration items (performed by the application’s System Administration) and evaluation of data readiness, as well as dynamic tests focused on basic system functionality. When necessary, a sanity test will be performed following the installation testing.



v. Security/Penetration Testing – It involves testing to ascertain how well the system protects against unauthorized internal or external access, willful damage, etc. This type of testing may require sophisticated testing techniques.

vi. Recovery/Error Testing - It involves testing to ascertain how well a system

recovers from crashes, hardware failures, or other catastrophic problems. f. Acceptance Testing – During the test scenarios definition, for each of the business

scenario, an acceptance criterion is defined. Acceptance criteria include expected behaviour of the software component and the expected results (data). Expected results form a part of the Exit Criteria. In addition to expected result and behaviour, some conditions are also specified in the exit criteria. They can be:

i. Number of bugs to be discovered for a functional module. This depends on

size of the functionality and is an indicator of amount of testing done.

ii. If any medium or low-priority errors are outstanding - the implementation risk must be signed off as acceptable by utility and Lead Partner along with consortium partners.

iii. All High Priority errors from System Test must be fixed and tested.

g. Lead Partner along with consortium partners needs to get the acceptance criteria

approved from utility for all the functional components of the system. The Acceptance Criteria for each release into production environment will be agreed upon by Lead Partner along with consortium partners in consultation with utility prior to release from Testing to production environment. After installation, if any bug is reported or there is non-compliance to requirements then a proper procedure should be followed. End-user should report (“Change Request”) to his/her supervisor about the bug that will in turn get forwarded to Project Manager (PM). PM will forward the List of change request to Lead Partner along with consortium partners. After the bug is fixed, it should be reflected in the production copy after testing it

h. Performance Testing - The bidder has to test and demonstrate the operational performance requirement as defined in the clause 9 of the specification after completion of entire scope. This will be part of acceptance testing. The system will be taken over by owner only after successful operational performance testing. The bidder has to arrange necessary hardware / software to demonstrate the performance testing.



i. Bidder should note that DHBVN can appoint a third party agency for conducting any part of above testing procedures (in addition to the testing carried out by the bidder).

44. Safety Precautions: - The Implementing Agency shall observe all applicable regulations

regarding safety on the Site and shall be fully responsible for the safety of man and materials.

45. Progress Report: -The suppliers will have to submit fortnightly progress report to the Chief Engineer (Material Management)-DHBVN every month following the month in which the order is placed if any, on the progress made by the supplier towards proper execution of order.

46. License for Electrical Work :- Contractor/sub-contractor, who is executing the erection,

testing and commissioning work at site should have electrical license issued by Chief Electrical Inspector, Govt. of Haryana. Copies of the license shall be submitted to engineer-in-charge before commencement of the work.

47. Data Analysis Provision in MDAS System: - MDAS system should have provision to

analyze the meter data and generate exception reports regarding the consumption behaviour, tampering, meter/modem malfunctioning etc. All these reports requirements will be finalized with the selected bidder during the system designing phase. Few examples of reports shall be as follows

a. CT Open / Reversal / Overload b. Intermittent Voltage Failure c. Load or Voltage Unbalance d. Load Factor (low/high) e. MDI greater than Sanctioned Load f. Neutral Disturbance g. Power Factor below given value h. Prolonged Voltage Failure i. High / Low Consumption j. Number and duration of power interruptions during a given period k. Revenue loss due to power-interruptions l. RTC failure, etc.

48. Rejection of Material :-

a. All the materials reported rejected should be replaced free of cost by the Contractor.



b. To and fro transportation cost for replacement of material shall also be borne by the Contractor.

49. Initial foot survey is to be done by the Implementation Agency of DHBVN area to collect basic parameters of consumers & meters and to identify exact number of selected LT, HT and DTs on which the metering units & related accessories are to be installed.

50. Foot Survey shall be done by the Implementing Agency before start of work for each lot (15,000) of connections. After the foot survey of each lot, Implementing Agency shall submit final Bill of Material and information collected from the field related to consumers and metering. IA shall start the implementation work after getting approval from DHBVN on Final BoM and Survey Data.

51. All the licenses shall be procured/supplied in the name of “Dakshin Haryana Bijli Vitran Nigam, Hisar”

52. All the licenses shall be owned by DHBVN even after the end of “Contract Period”.

53. The purchaser shall be at liberty to deploy the solution anywhere within the state of Haryana

54. The bidder should, if it feels necessary, study on its own, at its own cost, the existing status, data, consumer base, in the geographical spread of the DHBVN. The bidder shall structure the proposal as per the requirement of the system/solution being envisaged. Utility under no circumstances shall accept any disclaimers from Successful Bidder on this account. The ‘out of scope’, ‘exclusions’ and ‘assumptions’ having cost implications will not be entertained and will be treated as deviations.

55. DHBVN will define own archiving and data / document retention policy. The Implementing

Agency will implement and observe these policies during the O&M period.

56. Cost of bandwidth at Central data center and that on SIMs shall be borne by the Bidder.

57. Bidder shall establish a Help Desk after completion of first 15,000 connections. This desk shall act as a single-point-of-contact for all service problems pertaining to metering, modems, network, IT hardware and software. The successful bidder shall create and maintain a dedicated centralized online Help Desk with a telephone number, E-mail and call tracking mechanism that will resolve problems and answer questions that arise from the use of the offered solution as it is implemented in the utility. Users can log the queries / complaints, which should be resolved as per the Service Level requirements. The helpdesk queries / complaints can be related to connectivity, messaging, security, Hardware, Software, configuration and any other issues. Help desk shall submit a daily report to DHBVN



officials. Various MIS reports required from the Help desk shall be designed with the selected bidder.

a. Help Desk software shall take care of classification, automatic escalation,

management, and status tracking and reporting of incidents as expected by the service level requirements. Status tracking should be available to users through telephone number as well as online through software.

b. The Help Desk will respond to and resolve the problems as per the SLA. c. Problems shall be prioritized with level-wise classification as mentioned in the SLA.

The assigned priority for each problem shall depend upon: i. The extent of impact of the problem on the usability of the system.

ii. The Percentage of users affected by the problem. d. The initial assignment of priorities is the responsibility of the Help Desk’s Problem

Manager on basis of SLA. However, utility can change the priority assigned to a particular problem and the procedures that exist for escalating a problem to progressively higher management levels, until agreement is secured.

e. Help Desk shall be responsible for change management like schedule up gradation of hardware and software components etc. Help Desk will co-ordinate and take approval from utility for the same and will inform all users for such event in advance.

58. Vendor Management Services by Selected Bidder:- As part of O&M Support, the Selected

Bidder team will provide following services (but not limited to) during the O&M Phase. a. Manage the vendors for escalations on support b. Logging calls and co-ordination with vendors c. Vendor SLA tracking d. AMC Tracking e. Management of assets sent for repair f. Maintain database of the various vendors with details like contact person, Tel. Nos.,

response time and resolution time commitments. Log calls with vendors Coordinate and follow up with the vendors and get the necessary spares exchanged.

g. Analyze the performance of the vendors periodically (Quarterly basis) h. Provide MIS to utility regarding tenure of completion of AMC with outside vendors

for software, hardware & networks maintenance so that utility may take necessary action for renewal of AMC. FMS vendor shall also provide MIS regarding performance of said vendors during existing AMC.

59. Resources for Maintenance Phase (5 Years):-The bidder shall deploy adequate number of personnel (at-least two engineers at Hisar and sufficient support at each circle level) for providing Maintenance services in each shift of the day.



60. Service Availability and Criticality Chart during contract period

Service Duration Criticality Help Desk at Central Location 8 Hours per day - 6 days a Week URGENT Maintenance Support team at Circle Level

8 Hours per day - 6 days a Week MEDIUM

Vendor Management Services 8 Hours per day - 6 days a Week MEDIUM Data Center and Storage Maintenance Services

8 Hours per day - 6 days a Week HIGH

Backup Management As per Schedule MEDIUM MDAS Application Maintenance Services

8 Hours per day - 6 days a Week MEDIUM

61. Technical Proposal Structure :- The Tenders submitted by the Tenderers shall comprise of

the following documents:- • Section 1 – Executive Summary of the Proposal

o Executive Summary of Proposal o Joint Venture / Consortium Arrangements o Power of Attorney o Company Information o Summary of Experience and References

• Section 2 – QR and Bid Forms

• Section 3 – Solution Overview

o AMR Implementation and High Level Architecture o Replacement of Meters and Meter Boxes o Operation and Maintenance o Roles and Responsibility of each consortium member (in case of consortium) o Quality Assurance Policy ad Detailed Planning

• Section 4 – AMR Solution Implementation

o Summary of Implementation Strategy o Approach to maximize Benefits o High-Level Architecture of proposed solution o Project organization and Team Compositions o Skill and experience & CVs of key roles o Products and solutions - logistics, packing and shipping o QA Plan – audits, hold points, failure rates o Installation Methodology, Risk Assessments, Method Statements



o Sample Method Statements for Electrical Installation Activities o Site Safety and QA Audit Schedule o Overall consolidated Project Implementation Plan o Site Testing & Commissioning – Schedules, test equipments, etc. o Trainings o Interface with R-APDRP (Part-A) System, SCADA System and other existing and

future systems.

• Section 5 – AMR Operations and Maintenance (1 + 4 Years) o Summary of Services and Operations o Organization and Management Structure with detailed organization Chart o Process for Data Acquisition, Modem Configuration, Scheduling etc. o AMR System Performance and Availability o Backhaul Data Communications – Provision Details o Proposed Reports o Maintenance – Corrective and Preventive o Fault Rectification Process o Equipment’s Defects, Warranty and Failure Rate

• Section 6 – Products and Material Details

o Three phase Whole Current Meters o Three Phase CT Operated Meters o AMR Modems (GPRS/CDMA) o Meter Cover Boxes(MCB) o IT Hardware o Meter Data Acquisition Software o Desktops o Any Other Items o Self-Certificate for 100% compliance on following material

Three phase Whole Current Meters Three Phase CT Operated Meters AMR Modems (GPRS/CDMA) Meter Cover Boxes(MCB) IT Servers

• Appendix - A

o Key Staff CVs o Technical Data Sheets, Brochures and Type tests o ISO certificates



o Schedule of Non Conformance o Implementation Schedule – Implementation Phase o Implementation Schedule – O&M Phase o Proposed Sub-contractors for major items of plant and Installation Services o Others – Commercial or Contractual aspects of the bidding documents that the

bidder would like to discuss with the Employer during clarifications. o Any Additional Information - Any other material required to be added and /or

submitted by Tenderers in accordance with these Instructions to Tenderers and the technical Addendum to the Tender Data Sheet

o Manufacturer Authorization Formats



Section 6: Technical Specifications of AMR Software

The main objective is to acquire meter data from System and Select consumers meters automatically from remote location, avoiding any human intervention, Monitor important distribution parameters, use meter data for accurate billing purposes and generate exceptions and MIS reports for proper planning, monitoring, decisions and taking corrective actions on the business activities by the management. This objective under the project is achieved by providing an Automatic Meter Reading (AMR) based Data Logging System using any of the available Communication Technologies viz. GPRS, EDGE, CDMA and any other proven technologies covering all the connections having load between 10kW to 50 kW, selected HT and DT connections. The meter data from all distribution transformers as well as HT consumers will be transmitted to the central data center server(s) through GPRS/EDGE/CDMA/any other proven technology. The proposed Data Logging system is expected to provide continuous on-line monitoring and logging of essentially, though not limited to, the following parameters in respect of all incoming and outgoing feeders, Distribution Transformers and consumers on real time basis : -

i. Voltage, Phase to Phase and Phase to Neutral ii. Current on each phase iii. Power factor iv. Frequency v. Power - Active / reactive / Apparent vi. Energy – Active, Reactive and Apparent

The proposed system is expected to provide continuous on-line monitoring and logging of above mentioned parameters and capability to generate Spread Sheets and MIS reports as noted below:

i. System outage / downtime feeder wise. ii. Energy balancing at sub stations. iii. Daily peak loads feeder- wise / transformer wise. iv. Peak Load of the Station. v. Bus bar profile. vi. Daily Log sheets & any other forms / reports as required by the Utility



Specifications of MDAS System Requirement ID

Functionality Description Criticality

1 System features :-

1.1 Provision to collect and manage meter data

A system that collects and comprehensively manages meter data from system (utility network) meters and select consumer meters using MODBUS/DLMS/COSEM/IEC/ANSI/EEE compliant protocol. As most of the meters provided presently are DLMS complaint, DLMS shall be the preferred mode of communication

Vital

1.2 Remote capturing of meter data from system & select consumer meters

A system that captures the meter data remotely from all the meters at Distribution Transformers and HT/select LT Consumers for sending it directly to the remote collection center i.e. central data center.

Vital

1.3 Provision of communication media

The system provides for GPRS/EDGE/CDMA or any other suitable Communication technology between Meters located at Distribution transformer/HT/LT consumers and Data Center.

Vital

1.4 Optimal utilization of meter data

A system that optimally utilizes meter data for distribution management and billing.

Essential

1.5 Provision of a decision support system

A decision-support system for distribution operations, asset management and planning actions, e.g. Peak load monitoring shall help in finalizing the requirements for creation of additional electrical network element or up-gradation of existing electrical network element to meet the increased demand / load growth, Power factor monitoring shall help in capacitor placement requirement, voltage

Essential



Requirement ID


monitoring shall help in identifying low voltage areas for network up-gradation, data captured on imbalance between phases for DT, substation and 3 phase consumer meters can be used to increase reliability/plan load balancing jobs / advise customer to transfer loads between phases etc.

1.6 Identification of poorly performing areas

A system that pinpoints poorly performing areas in the distribution network, based upon the technical parameters, such as area wise distribution losses, theft, outages, overloaded circuits/equipment, voltage imbalance, reliability indices, power quality etc.

Vital

1.7 Helping in network upgrade actions

A system that aids decision-making on network upgrade actions by leveraging of historical meter data to calculate area-wise load growth, equipment wise, downtime/outage statistics, seasonal effects and usage pattern for long term and short term planning.

Essential

1.8 Enabling health and performance monitoring of assets

A system that enables ‘health’ and performance-monitoring and management of important system assets (feeders/ transformers).

Essential

1.9 Detection of HV/DTR outages

A system that enables quicker, ‘event-driven’ detection of HV/DTR outages thereby improving reliability indices and customer satisfaction.

Essential

1.10 Monitoring of customer performances

A system that enables monitoring of customer “performance”, e.g. contract demand violation, peak load violation, tamper counts, average power factor etc.

The system should also have provisions to cover usage patterns to solve high

Essential



Requirement ID


consumption complaints, facilitate calculation of assessed readings for stopped meter cases, and detect low consumption cases by comparing average historical consumption with actual consumption.

1.11 Enabling dispatch of event notifications

A system that enables dispatching of event notifications to targeted recipients for faster field response and decision making.

Essential

2.0 Scope of deliverables :

2.1 Supply /installation of Hardware

Supply and installation of Server, Work station/HMI with Printer and all other hardware system for data logging system at required locations.

Vital

2.2 Application software for capturing, validating and analyzing the Meter data

Application software for capturing, validating and analyzing the Meter data at the Central Data Center scalable for a size of 1.5 Lacs Consumers

Vital

2.3 Application software at data center

Application software for acquiring incremental meter data from Data logging system of all the sub division offices under the utility area for aggregation, analysis and generation of various MIS reports through appending of the Metering module.

Vital

2.4 Supply/ installation of Modems at DTs and HT/ Select LT consumers

Supply and installation of suitable Modem (GPRS/EDGE/CDMA) at meter ends for communication between Meters located at Distribution transformer and HT/select LT consumers and Data Center servers. If required necessary, the Modem may be retrofitted on optical port of the meter.

Vital



Requirement ID


2.5 Supply/ installation of any other equipment or accessories

Any other equipments or accessories required for operation of the system.

Essential

3.0 System Architecture: General Notes

3.1 Provision of an integrated software system to meet the functionality of AMR

An integrated software system should be provided to meet the following Functional requirements spanning Automated Meter Reading :-

Real Time data acquisition from Meters Historical data acquisition from Meters Supervisory function i.e. processing,

monitoring, analysis and diagnostics Data exchange Storage of data Report generation and reporting Facility for user defined forms and

reports e.g. calculation of Feeder/ DT performance statistics

Facility for time synchronizing Alarm list Event list Limit value violations

Vital

3.2 Flexible deployment / implementation of software system

The software system deployment/implementation should be flexible.

The deployment should be web based and there should be no need for any installation / licensing at client end

Vital

3.3 Web Based software system

The software shall be web based system for automatic data display and reporting

Essential



Requirement ID


3.4 Provision for local / remote data collection

The software shall have option for data collection from meters connected locally or in remote locations, through modem communication.

Vital

3.5 Facility for Web based front end

Software shall have web based front end. Essential

3.6 Provision for flexibility, user friendly and scalability

The software system shall be flexible in terms of System & Application software, user friendly and scalable upwards and downwards.

Essential

3.7 Software system with robust architecture, high availability and reliability

The software should be based on a robust architecture model / framework that is highly scalable/available/reliable, gives good performance, and offers distributed computing.

Essential

3.8 N-tier design methodology

The software would be designed with multi-tier (N-tier) design methodology. It should have distinct tiers representing the client/ business/database layers etc.

Vital

3.9 Client tier The client tier will be the interface of the software with the utility’s operations/ dashboard user. The client tier will provide all the user interfaces for the operational and supervisory activities involved in meter data acquisition, processing and analysis.

Vital

3.10 Business logic tier The business logic tier would service the requests made by the client tier. These requests could be automated, based on user-defined schedules or on-demand from the user.

Vital

3.11 Automatic workflow process from data acquisition to

Normal workflow processes from meter data acquisition to analysis would be as automated as possible; for example user intervention would be sought only for data editing or

Essential



Requirement ID


analysis verification decisions.

3.12 Database tier The database tier should comprise of an RDBMS that should be designed to be able to maintain the relationships between meter and network assets, network topology, user privileges, service points, customer accounts and other entities.

Vital

3.13 Maintenance of time stamped database

The database should also maintain a time-series repository that stores the data collected and processed from meters, including interval usage data, event logs and outage history, as well as derived data such as aggregations and asset performance indicators like load factor and load duration curves.

Vital

3.14 Optimal designing of database

The database tier should be optimally designed to exploit both normalized as well as multidimensional data models.

Desirable

3.15 Provision of OLTP and OLAP models

Both OLTP (Online Transaction Processing) and OLAP (Online Analytical Processing) models should be exploited for ensuring performance and scalability.

Essential

4.0 Features of Data logging system

4.1 Main areas of data collection

The software will in general collect the following data from the meter -

Billing Data Load survey profiles Tamper data Date and time of collection of data Instantaneous parameters at the time of

collection

Vital

4.2 Typical list of data A typical list of data acquisition from the Essential



Requirement ID


acquisition from the Meters

Meters has been mentioned below :

Acquire real time instantaneous data like voltage, current frequency, power factor, active power, reactive power etc. at the specified regular intervals ( 15 minutes-30 minutes as per meter specification) for online monitoring anywhere across utility.

Acquire stored historical values of data at regular interval with power consumption, accumulated energy, accumulated power, maximum demand and other parameters.

Acquire real values of specified parameters on demand.

Synchronize date and time of all meters. 4.3 Provision of

generating critical events

Software shall be able to provide details of critical events (e.g. No communication with Meter, Power failure etc.) and necessary provision should exist to report the correct event to user.

Essential

4.4 Provision of manual entry of data in case of meter change

Software shall have facility to enter manual readings & associated data for taking care of meter change on feeder, but only with appropriate user identification, security and audit trail.

Essential

4.5 Seamless transfer of data even in case of meter change

Software shall show and transfer data seamlessly even in case of meter change. An indication of meter change shall be available.

Essential

4.6 Facility for back up and restoration of data

Facility for taking backup & restoration of data collected at Data Center shall be provided in software.

Essential



Requirement ID


4.7 Periodicity of data collection

System shall be capable of collecting data from all the HT and LT consumers at least every half Hour and from all the Distribution Transformers at least once in 24 Hours.

The number of HT and LT consumers and number of DTs have been furnished in the SRS Document. However, the bidder may visit the area and collect the exact details about the number of HT consumers and number of DTs at site and design and supply the system as per actual availability at site. Further, the system shall be designed and shall have provisions for inclusion of new Consumers and Assets in future and shall provide additional spare capacity to cater 7.5% per annum growth over and above the actual requirement at site on account of the future provisions.

Vital

4.8 Availability of sufficient storage capacity

The system shall have sufficient memory capacity for storing every Analog, Digital and Accumulator data of all connected remote Data loggers in the substations as well as all DTs and Consumer data for a period of at least one year.

Vital

4.9 Generation of DT wise, Sub Division Wise, Division Wise and Circle Wise wise data base

The software shall provide DT wise, Sub Division Wise, Division Wise and Circle Wise database for generating summary reports, statistical data, performance indices etc. In user defined forms.

Essential

4.10 Ability of software to integrate, extract and analyze data of different make

Software shall be capable of collecting data on a common data structure / format from DT meters and HT/select LT consumers of various manufacturers. The data logging software package should be able to integrate, extract

Vital



Requirement ID


of Meters

and analyze data of different makes of Meters.

4.11 Manual/ automatic mode of data transmission

The modems (remote devices) should automatically push the data at pre-configured interval of time. There should be option for changing the frequency of data transfer from the central server.

There should be provision for manually dialing the modems connected to the DT and Consumer meters or by configuring the software to collect the data from meters automatically with the help of Scheduler feature provided for auto dialing.

Essential

4.12 Viewing / exporting of collected data

The collected data can be viewed in the form of customized reports. User can take print-outs of these reports, export the data into spreadsheets, or convert the data in the form of flat file.

Essential

4.13 Facility for archiving, deletion, backup & restoration of the data

Facility for archiving, deletion and taking backup & restoration of entire or part of the data collected at Data Center office shall be provided in Software.

Essential

5.0 Meter Data Acquisition: software requirements

5.1 Mode of Data Transfer from DT/HT/LT Connections

The Data acquisition software at central data center must have the following functions : a) Data Collection: It shall collect Meter data directly from DTs, HT and LT consumers through GPRS/EDGE/CDMA Modems and store in the database.

Vital



Requirement ID


b) Data Processing: It shall use data from the database to create reports, charts and spread sheets. c) Data transfer to data center : All the modems should be able to transmit the meter data to central data center which shall reside in the Metering module for further aggregation, analysis and MIS generation as per request from various utility offices d) Messaging : Via GPRS/EDGE/CDMA e) Program Generator: It shall have editors and configuration software. f) Facility to communicate with multiple clients simultaneously through multiple communication lines. g) The communication shall be scalable and configurable to various media like CDMA, GPRS, and EDGE.

5.2 Configurable data collection engine for meters of different makes

The Data collection engine of the Data logging software shall be configurable for Meter of different make and shall have the ability to perform remote data acquisition from system and customer meters.

Vital

5.3 Enabling of data acquisition from different AMR configuration

The software will enable data acquisition from different AMR configuration schemes (based on location and selection of system/consumer nodes)

Vital

5.4 Enabling of data acquisition over any communication media

The software will enable data acquisition over any of the locally and reliably available communication media : GPRS, EDGE, CDMA etc.

Vital



Requirement ID


5.5 Provision to configure and manage technical parameters for communication media

The software will be able to configure and manage technical parameters for the communication media used in the project.

Vital

5.6 Provision of remote reading & collection in both scheduled & batch mode

Remote reading collection will be possible in data push form from the field devices in automated as well as in the on-demand (real-time) mode.

Vital

5.7 Features of data collection

Data from remote AMR devices will be acquired automatically. Software will allow reading cycles to be configured for either individual meters or groups of meters. Appropriate time windows for data collection from different meters at pre-configured interval of time to the Data Collection Server at the Data Centre can be set. The data collection could be effectedat any one of the pre-defined daily, hourly or quarter-hourly frequencies or at any user-defined frequency greater than 15 minutes.

Vital

5.8 Support for both inbound and outbound communication

The software will support both inbound and outbound communication, i.e. data transfer could be initiated by either the remote meter in general or the central software in case of special requirements.

Vital

5.9 Type of Inbound communication

The minimum, inbound communication will include event notification calls for power outage and restoration events.

The event driven polling of meters shall enable pinpointing of faults during outages, defective or stopped meter.

Essential



Requirement ID


5.10 Type of outbound communication

In outbound communication, the number of retries made by the software for failed meter readings will be configurable. If the meter cannot be read even after the specified number of retries, the system will raise an alarm and generate meter reading exceptions to enable tagging of cases for site verification.

Essential

5.11 Ability to retrieve both instantaneous and logged data

The software will have the ability to retrieve both instantaneous and logged data from the meter.

Essential

5.12 Support for import of meter data

The software will support import of meter data from external sources in industry-standard formats like ASCII, CSV or XML. It will also allow manual entry of meter data in exceptional cases only with appropriate user identification, security and audit trail. The input sources of meter data could be CMRIs (Common Meter Reading Instruments), substation log books etc.

Essential

5.13 Synchronization of all meters to a common fixed reference

The software will be able to synchronize the date and time of all remote devices to a common fixed reference.

All the raw meter data entering the system via AMR or any external means is time-stamped and stored for audit and further analysis.

Essential

5.14 Mode of transfer of Meter data

The data will be transferred from various AMR devices/data loggers to the data center server in one of the following possible methods :-

a) Automatic Data Transfer

By default, data shall be automatically sent in push mode by the AMR devices/data loggers to the Data Centre at preconfigured time interval.

Vital

b) Manual Request for Data

Under special circumstances there should also be a provision to get the data on manual

Vital



Requirement ID


request from AMR devices/data loggers 6.0 Network Topology Management

Ability to capture and maintain the geographic / administrative / regional hierarchy

6.1 The software will be able to capture and maintain the geographic / administrative / regional hierarchy of a utility’s control area, i.e., the tree hierarchy of zones, circles, divisions, subdivisions and substations constituting a utility.

Essential

Ability to capture and maintain the electrical network topology

6.2 The software will be able to capture and maintain the electrical network topology, i.e. substations, feeders, transformers and HT consumers.

Essential

Flexible and Indian context oriented regional hierarchy and topology

6.3 Both the regional hierarchy and topology would be specific to the Indian context and flexible enough to account for different voltage levels in Indian sub-transmission and distribution networks e.g. 66/33/22/11/ 0.4 KV.

Essential

Provision to capture and maintain associations between various metering nodes

6.4 The software will be able to capture and maintain associations between various metering nodes (both system and consumer meters) and the regional hierarchy / network topology.

Essential

Typical list of System metering nodes

6.5 System metering nodes could include AMR-enabled meters located at these network points, among others: (i) Outgoing feeders from grid substations (at 33kV/ 11kV etc), (ii) Incomers (33kV etc) at the power/secondary substations, (iii) Outgoing feeders (11kV/ 0.415kV etc) from the power/secondary substations, (iv) inter-region power import / export tie-points on sub-transmission/ distribution feeders, (v) Distribution transformers (DTR)

Vital



Requirement ID


primary/secondary.

Typical list of Consumer metering nodes

6.6 Consumer metering nodes could include AMR-enabled meters located at the service points of selected H.T./L.T. consumers (e.g. those with load above 10 KW)

Vital

Provision for modification in existing metering nodes

6.7 The software will allow modification of existing metering node parameters.

Essential

Provision to add virtual metering nodes

6.8 The software will allow addition of virtual metering nodes and associate the same to the regional hierarchy / network topology.

Essential

Provision to Navigate to any level of the regional hierarchy/ network topology

6.9 Navigation to any level of the regional hierarchy / network topology would be simple and intuitive via drill-down mechanism.

Essential

Provision to display SLD

6.10 Software will be able to display SLD schematics for important network areas.

Essential

Provision to depict Single line diagram

6.11 Software shall have facility for creating data base and display of single line diagram of entire electrical network and embedding of acquired data (both analog & digital) of each feeder in real time.

Essential

7.0 Data Validation, Editing and Estimation (VEE)

Supporting of automated rule-based validation

7.1 Software will support automated rule-based validation and estimation of raw metered data.

The system should trigger The validation process automatically as and when the data is received from Meter data collection system built in validation routines: The system should

Essential



Requirement ID


have pre-defined validation rules that can be adjusted by user inputs. System should also have ability to define new validation and estimation rules. Detailed requirements need to be finalized by Implementing Agency along with utility

Supporting of multiple data states

7.2 The software would support multiple data states for metered data through its transition from acquisition to analysis e.g. invalid, estimated, edited, verified, validated etc.

Essential

Configuration of validation rules

7.3 The software will allow configurable validation rules that may be selectively applied to an individual metering node or groups of metering nodes or to channels common to different metering nodes.

Essential

Logging of validation failures

7.4 Validation failures would be logged for audit purposes.

Essential

Backing up of raw data

7.5 Raw data would be backed up for audit purposes.

Essential

Provision of meter data estimation routine

7.6 The software will have a meter data estimation routine that will be triggered on occurrence of validation failures.

System should also have facility to define, add and revise estimation methods.

Essential

Enabling of estimation routine

7.7 The estimation routine can be selectively enabled/disabled.

Essential

Provision of manual editing

7.8 The software allows manual editing of metering data with audit trail.

Essential

Provision for audit trail

7.9 All data state transitions would be logged for audit trail.

Essential



Requirement ID


8.0 Data Analysis & Charting Processing of validated meter data

8.1 The software will enable processing of validated meter reading data for generation and storage of different time series channels. A channel would hold data pertaining to one particular parameter.

Essential

Support for multiple channels for multi parameters

8.2 The software will support multiple channels for multi-parameter such as Voltage, Current, Frequency, Energy, Energy demand, performance indicator and event related data.

Essential

Support for channels of different time series

8.3 The software will support channels of different time granularities, i.e. hourly, daily, monthly etc.

Essential

Support for different channels for different type of data

8.4 The channels could hold direct measured data, derived (calculated) data, or data imported from external sources.

Essential

Viewing of time series data in tabular / graphical form

8.5 User will be able to view time series data in tabular as well as graphical format.

Essential

Ability to show status of time series data element

8.6 The software will be able to highlight the state of a particular time series data element, e.g. if it is absent, edited, estimated etc.

Essential

Comparison of multiple time series data

8.7 The software will enable user to compare multiple time series together. The data series could pertain to the same channel or different channels.

Essential

Facility for automated filling up of certain

8.8 Automated filling up of certain derived time series channels based on data in one or more other channels will be enabled; e.g. data for the

Essential



Requirement ID


derived time series channels based on data in one or more other channels

power factor channel of a particular metering node can be calculated using the data in the active power and reactive power channels of the same node. The latter two may have been directly filled with measured data from the meter.

Provision of setting/editing of the conversion formulae

8.9 The software will allow setting / editing of the conversion formulae for the derived channels. The conversion formulae can be based on simple arithmetic / trigonometric / aggregation functions.

Essential

Provision of aggregation of time series data

8.10 The software should allow aggregation of time series data based on parameters like geography (regional hierarchy), network topology, time and customer category

Essential

9 Executive Dashboard

Provision of Executive dashboard at various utility offices

9.1 Various utility offices, such as Circle, Division, Sub division etc., can interact with master Metering (AMR as well as non AMR enabled) / Billing database at data center to provide the below mentioned features.

Provision of selective monitoring of summarized data

9.2 The software would support selective monitoring of important summarized data at user-defined intervals that would aid in decision-making for distribution operations and planning actions.

Essential

Highlighting of key performance indicators

9.3 Key performance indicators like AT&C losses, SAIFI, SAIDI, and CAIDI (but not limited to) will be highlighted for every level of the network hierarchy.

Essential

Energy balance at different network

9.4 Energy balance at different network levels will be captured and displayed. This enables

Essential



Requirement ID


levels monitoring losses by region (subdivision/division /circle etc.) and by network asset (transformer/feeder).

Monitoring of losses at different voltage levels

9.5 Monitoring of losses at different voltage levels will be enabled.

Essential

Display of load survey analysis

9.6 The software will enable capture and display of data from multi-parameter load survey analysis. Monitoring of usage/demand patterns would thus be enabled.

Essential

Monitoring of peak load

9.7 Peak load at different network levels could be monitored.

Essential

Monitoring of performance factors

9.8 Performance factors like load factor, power factor, utilization factor, load duration curves would be monitored.

Essential

Provision of transformer load management

9.9 The dashboard will enable transformer load management. User will be able to monitor overloading/ under loading, phase imbalance, load factor, utilization factor, load duration curves of transformers.

Essential

Provision of Feeder load management

9.10 The dashboard will enable feeder load management. User will be able to monitor overloading / under loading, phase imbalance, load factor, utilization factor, load duration curves of feeders etc.

Essential

Personalization as per the user’s preferences.

9.11 The software would support personalization of the dashboard displays as per the user’s preferences.

Essential

Navigation from one level of network hierarchy

9.12 Navigation from one level of network hierarchy to another will be intuitive and

Essential



Requirement ID


to another drilldown will be possible

10 Reports

Generation of reports based on the results of data analysis

10.1 The software will be able to generate and display reports based on the results of data analysis. The reports module will be used as a more data-heavy alternative to the Executive Dashboard.

Essential

Reporting on energy flow, performance factor etc.

10.2 The software will be able to display reports on all energy, demand, performance factor and event related data available for different metering nodes.

Essential

Generation of reports with date range

10.3 Each report will allow user to specify parameters like date range, end points for which reports need to be generated.

Essential

Type of reporting 10.4 The reports could be either Windows or Web based.

Essential

Exporting of reports to other applications

10.5 The software will enable the user to export reports into other application software like ERP, Microsoft Excel etc. for further processing.

Essential

Reports at Data Center

Provision for comprehensive reporting and MIS facility

10.6 Software at Data Center shall provide comprehensive reporting & MIS facility and it should provide fixed format as well as query based reports in tabular & graphic format as required by user.

Essential

Option to view data selectively in numerical / Graphical form

10.7 The user should have option for viewing selective data like Instantaneous parameters, Cumulative Energy Readings, Tamper information, Tariff-wise Billing Data for each reset backup, Load Survey data, Meter Programming records. Option should be

Essential



Requirement ID


provided to view the Load Survey data in both numerical as well as In Graphical format with selective or composite view of parameters and in different styles viz. bar and line.

Generation of summary report of meter data for any load violation and tamper counts

10.8 The software should scan through each meter data and generate a summary report of billing data, contract demand violation / peak load violation/ off day’s violation along with tamper counts for that particular meter.

Essential

Provision of menu option for viewing each data report

10.9 Menu option shall be given for viewing each data reports. The options will be enabled based on the availability of the data for the meter selected for data viewing. Each report header should give the information regarding the Meter serial Number, RTC, Date and Time of data collection, Type of collection, CT/PT details and other important consumer details.

Essential

Typical list of reports to be generated

10.10 Reports should provide detailed information on Billing data, Load Survey data, Profiles, Tamper information, Programming mode records and other system irregularities. Following is a representative list of reports for different levels of the network hierarchy and for different timeframes. • Energy balance report • Consumption trends report • Load factor report • Reliability analysis Report • Asset utilization report • Electrical network monitoring report

Essential

Availability of extensive search options

10.11 User should have extensive Search option for search using Meter number, Consumer Number, Consumer Name, Location, and Date of Reading of meter. An explore option should also be given for listing out all the meter data available in the system. This menu option will

Essential



Requirement ID


provide the list of data files sorted in the order of serial numbers, consumer account number and location.

List of a few typical reporting requirements

10.12 Few typical reporting requirements are mentioned below, exact formats & requirement may be finalized as per the requirement of the Utility.

Display of Electrical Parameters (Load current in Amp, power factor, frequency, voltage, active, reactive and apparent power etc.) in Tabular Formats and as Trends (Graphs) Over Periods (e.g. for a week or month)

Comparative tabular & graphical reports for more than one meter & more than one parameters (comparison of pure values as well as Min, Max, Sum, Average)

Min, Max, Sum, Average electrical parameters values, its time of occurrence and duration of maximum and minimum values

Graphical Display of Maximum Power Demand Analysis

Software shall have facility to query data based on dates & parameter name

Software shall be able to show trend for single parameter & comparative trend for multiple parameters based on the selection.

Support for sending report using Email or Alerts

User Configurable Reports using MS Excel Detailed Error Reporting and diagnosis

through Log Files and online display of Error Status

Printing and Exporting of Reports to MS office.

% availability factor of feeder (i.e. % of time for which power was available for feeders to know the reliability index of the feeder)

Essential



Requirement ID


Reports at various Utility offices, such as Division, Circle, Head Quarter etc. :

Reporting facility at various utility offices

10.13 Web based Reporting Software shall be available through web browser to various utility offices, which can interact with Metering/ Billing database at Data center to provide extensive analysis & reporting facility. It shall also have extensive search options and should provide fixed format as well as query based reports in tabular & graphic format

Essential

Geographic/ administrative/ regional hierarchy wise reporting facility

10.14 The various offices of the utility e.g. zones, circles, divisions etc. can login to the system for generating and viewing various MIS reports, statistical data, performance indices etc. as per their requirement.

Essential

11 Event and Alarm Notification

Monitoring of important events

11.1 The event list shall contain events, which are important for monitoring. The date and time hasto be displayed for each event.

Essential

Chronological registration of events

11.2 The events shall be registered in a chronological event list, in which the type of event and its time of occurrence are indicated. It shall be possible to store all events in the computer. The information shall be obtainable also from printed Event log.

Essential

Listing of faults, errors and limit value violation in alarm list

11.3 Faults, errors and limit value violation of all values occurring shall be listed in an alarm list. Audible annunciation must be provided on receiving alarm. It shall contain unacknowledged alarms and persisting faults. Date and time of occurrence shall be indicated.

Essential

Summary display of alarm situation

11.4 The alarm list shall consist of a summary display of the present alarm situation. Each alarm shall be reported on line that contains : Alarm date and time Name of the alarming object A descriptive text

Essential



Requirement ID


Acknowledgement state Acknowledgement of alarms

11.5 The operator shall be able to acknowledge alarms. Acknowledged alarms shall be marked at the list.

Essential

Typical list of items on which system can generate alarms

11.6 The system will analyze time-series / meter data and generate alarms/notifications. Following is the representative list of items on which system may generate alarms :

Alarms based on consumption patterns Alarms based on loading conditions Alarms based on tamper detection Alarms based on outage detection Alarm based on violation of limit values Ability to configure criticality / priority

of the events

Essential

Framework to configure thresholds for generating alarms at each end-point

11.7 The system will have framework that allows user to configure thresholds for generating alarms at each end-point. (e.g. one set of end points; user should be notified if daily consumption exceeds Y kWh and for some other end points alarms should be generated only if the daily consumption exceeds X kWh).

Essential

Alarm on failure in communication, loss of data etc.

11.8 The system will also generate alarms based on any failure in communication, missing/loss of data.

Essential

Supporting of alarm/ notification dispatch via communication media

11.9 The system will support dispatching alarms/notification using various communication media like SMS, E-Mail, Desktop Application etc.

Essential

Ability to deliver alarm/ notification to multiple recipients

11.10 The system will allow each alarm / notification to be delivered to multiple recipients. (e.g. alarms corresponding to outage at DTR level should be sent to a J.E. and an S.E.)

Essential



Requirement ID


Provision for turning certain alarm generation on/off as per user preferences

11.11 The system will allow turning on/off certain type of alarms generation (at system wide level or for particular end point) based on user preferences. (e.g. if one does not want any Communication Failure alarms, he/she can turn off the alarm generation for this criterion)

Essential

Provision for turning certain alarm dispatch on/off as per user preferences

11.12 The system will allow turning on/off dispatching alarm notifications to required recipients. e.g. if Chief Engineer, does not want to receive any alarms for some reasons, system should be able to turn-off the same)

Essential

Provision to acknowledge or ignore events / alarms

11.13 The system will allow user to acknowledge or ignore events/alarms. System will also allow user to log the actions taken, if any, for any particular event.

Essential

Setting of different priority levels for different events /alarms

11.14 The system will support different priority levels for different types of events/ alarms.

Essential

Provision of different dispatch schedules for different types of events/ alarms

11.15 The system will support different dispatch schedules for different types of events/ alarms. (e.g. Outage Alarms to be dispatched within 5 minutes of receipt and Contact Demand violation alarms should be dispatched before every billing cycle start)

Essential

11.16 Time synchronization

Time synchronization: The time synchronization shall be possible from the Work Station/ HMI through built-in function. An accuracy of ±1 milli second within the station is required. However provision is to be made available for time stamping through GPS. System should allow to configure the frequency of the synchronization

Desirable



Requirement ID


11.17 Administration Function

The MRS shall support the following functionalities:

• Defining of roles and users/user groups • Access control to System components • Administration of reporting functions • Execute a regular backup of all data at

the desired time. • Defining of user/user group rights

Vital

11.18 Reports on electricity quality

This reporting function would execute analysis of voltage circumstances on meters themselves since there are corresponding records in the electricity quality log recording voltage drop/overvoltage below/above defined voltage thresholds and supply interruptions. In this way, the function would indicate poor voltage circumstances with one or a group of customers and it would represent the reason for the crews to go out into the field.

Vital

11.19 Analysis of statuses and alarms

This type of reporting functions processes alarms and statuses of meters/concentrators, event logs, with the making of corresponding reports after finding corresponding alarms, statuses and events. Result of such reports should be available on daily basis , i.e. periodical report on the state clearly showing all alarms, statuses and events and on which meters, representing the basis for further action on these meters.

Vital

11.20 Communication reports

Successful statistics of communication between system elements represents special acknowledgement within the reporting functions

Vital

11.21 Reports – General features

All reports must be capable of being downloaded to Excel, ASCII or TXT file. Print/Print Preview option is mandatory with every report automatically generated in the form of PDF file

Vital

11.22 Voltage Variations The MRS system must show the endpoint registers with voltage variations in accordance with the meter parameterization or MRS configuration

Vital



Requirement ID


11.23 Common ASCII/XML File

A single common ASCII/XML file for all the Meters shall be generated for integrating the billing data with the existing billing system, irrespective of make & model of Meter

Vital

11.24 Analysis Reports – 1

Percentage slots, for which PF is less than 0.5, 0.5 to 0.7, 0.7 to 0.9 &> 0.9

Vital

11.25 Analysis Reports – 2

Percentage slots for which load <20%, 20-40%, 40-60% &>60% CD Consumption vis-à-vis Usage Index for the Industry, based on data Provided.

Vital

11.26 ARCHIVE DATA AND DATA RESTORATION

An archiving procedure should be implemented enabling efficient data storage for the time period of at least 5 years, and subsequent transfer to storage media providing permanent storage

Vital



Section 7: Technical Specifications of AMR Modems

Requirement ID Requirement Details

1.

The modem at DT/Consumer Meter end will have suitable interface facility to connect with the meter optical port by using the optical cord or RS232 cable. (If required, the Modem may also be Retrofitted on optical port of the matter).

2.

The offered modems should be capable of operating on Three phase supply. The operating voltage range for the modem should be 90 V ac P-P to 440 V ac P-P, so that the modem can be used on both HT & LT Trivector Meters. How-ever the modem should also be capable of operating on single phase 230 V, 50 Hz power supply. The modem shall be suitably protected against voltage surges.

The offered Modem should be capable of transfer of the entire data of Trivector Meter in less than 10 Minutes after connection is made assuming there is no line disturbance.

3.

The offered Modem should be supplied with power cable, antenna with co-axial cable of suitable length, RS 232 connecting cable, mounting adopter etc. and should be complete in all respects.

4. Sealing: - The modem cover and body should have arrangement for sealing. In addition to this, the SIM card holder cover should also have arrangement for sealing.

5.

Antenna: - The Modem should have flexible external antenna to enable placement of the antenna at the location of strongest signal inside the Metering Cubicle. Bidders are requested to quote separately for multiple gain antenna, such as OdBi/3dBi/10dBi with screw mount / Wall mount arrangement. The actual requirement of these Modem Antennas of various gains may vary as per the requirement at site. Bidder will be required to supply the exact requirement as per site conditions and will be paid as per the separate unit rates quoted for different Gain Antennas. Before supply of GPRS/CDMAmodem, the bidder is requested to ensure the availability of appropriate signal and operation of GPRS/CDMA Modem in all the areas to be covered by making physical survey or otherwise. Before making the actual supply of Modems for DTs and HT Consumers, the Bidder is requested to assess the exact requirement and should supply a high gain antenna or any other suitable alternate communication network for collecting data in such area.




6.

Outage Notification :-

In the event of an outage, the modem should be able to initiate separate call or send SMS to predefined numbers to notify the outage event with data and time of occurrence and restoration.

7.

Other requirements:-

A) The Modem should actas completely transparentchannel i.e. The Commands received from Data Center server should be conveyed to meter and data from meter should be conveyed to Data Center server without any changes in the modem.

B) Data collection from meter should take place only after connection is established between Data acquisition server and Meter. Data should not reside in the modem before the time of transmission to Data Center server, to avoid chances of tampering of data at Modem end.

C) The Modem should be capable of operating with SIMs of local GPRS/CDMA Service provider in the area.

D) Data enabled SIM card will be provided by the utility and monthly SIM charges will be borne by the utility.

E) Modem should be capable for continuous working for 24hours every day under field conditions, even when enclosed in Metering Cubicles at Consumer sites.

F) Software shall have facility for Auto-Scheduler to enable automatic / unattended data collection during night hours.

8 Modem shall be suitable for long duration data transmission and shall be protected against external interference of systems working at different bands.

9

Mechanical Specifications: - Modem should be a compact model housed in a polycarbonate / engineering plastic / Metallic enclosure. The modem should comply with IP55 degree of protection.

10

Environmental Specifications :- The Modem shall meet the following environmental specifications : -

Storage Temperature : -20 degrees to +70 degree Celsius Operating Temperature: -10 degrees to +60 degree Celsius Humidity:- 95% RH ( Non - Condensing)

11 Communication Capabilities: -

Modem should be Dual Band modem capable of operating at 900 and 1800 MHz




GPRS transmission. Modem should support both Data and SMS transmission. It should have

GPRS/CDMA &EDGE features.

12

Interface :-

Modem should have an RS232 Interface through a 9 pin or 15 pin D type Connector for connection to Meter through an Optical Port.

The SIM interface should be a 3 V Interface in accordance with GPRS/CDMA 11.12 phase 2 with a retractable SIM cardholder, which should be fully inserted inside the modem. The holder opening should have a sliding cover with provision for sealing after placing of the SIM card. The modem shall accept the standard SIM Card.

Modem should have a SMA Antenna connector

13

Power :-

Maximum Power Output should be 2 W at 900 MHz (Class 4) and 1W at 1800 MHz (Class 1).

The RF functionalities should comply with the phase II+ compliant, E 900/ 1800 recommendation.

VA Burden of the Modem should not exceed 3.5 VA during data communication.

14 Sensitivity :- GPRS 900 : <-100 dBm

GPRS 1800 : <-100 dBm

15

Data Features: -

Modem should use standard AT Command set for settings of the modem.

TCP/IP stack access via AT commands Internet services :TCP, UDP, HTTP, FTP, SMTP, POP3Max. Baud Rate

CSD Data transmission features

Data Circuit asynchronous and non transparentupto 14.4 kb/sec V.110 USSD Support

GPRS Data transmission features

GPRS Classs B Multi slot class 12 or class B Multi slot class 10 Packet channel support : PBCCH




Coding Schemes : CS1 to CS 4 complaint with SMG32(Release 97)

EDGE Data transmission features

EDGE (EGPRS) Multi slot class 12 or Multi slot class 10 Mobile station Class B Modulating & Coding schemes: MCS 1 to 9 Packet channel support : PBCCH

16

SMS Features: -

Text and PDU Point to point (MT/MO) Cell broadcast

17

Operational Indicator: - The Modem should have separate LED indications to transmit data to receive data, AC carrier detects and Power ON, etc. to indicate Power on position and to indicate the availability of signal at the place of installation.

18 Power Backup: - The modem should have power backup for 48 hours and can store and push the entire data to the central server in case of power failure.

19 Compliant with SIM: - The modem should be capable of operating with SIMs of local GPRS service provider in the area.

20

EMI/EMC Specifications :- The GPRS/CDMA modem shall meet the following EMI/EMC specifications

a. Electrostatic Discharge IEC61000-4-2

b. Fuel Transient Burst IEC61000-4-4

c. Surges Immunity IEC61000-4-5

d. Conducted Emission CISPR22 (class B)



Section 8: Technical Specifications of IT Servers

S. No Requirement Description

1 System Hardware

The servers shall be enterprise level SMP RISC / Itanium processor based systems The offered systems should be high end Datacenter class servers with redundancy / N+1 features built in at every level like disk, memory, power supplies, cooling etc.

2 Operating System

The operating system of the server shall be 64 Bit. The Operating System shall be of the latest version released by the OS vendor. The OS shall be supplied with media and complete documentation shall be provided for each server. The OS license shall be provided for each partition with separate independent instances of the OS in the server. Latest version of OEM operating system shall be provided for each server, with required number of user license on each server ( At least 4 for each server) The OS shall have standard features and networking support i.e. TCP/IP, NFS, NIS, CDE, BSD tools etc. Disk mirroring & stripping support shall be included. OS shall be given with the latest patches as applicable and OS should have minimum features like full binary compatibility across versions, online OS upgrades and online kernel patching/upgrades, standard GUI utilities for system administration, virtualization using soft partitioning with minimal or no performance overhead, online error detection and prevention of critical hardware components, provision to analyze system performance bottleneck in real-time, security features like built-in firewall, Role based access, Access control list, Process based privileges, TCP wrappers, IPSec, Smart card support , Pluggable Authentication modules and more. Vendor should provide clear reference to these features. An Open Source Version of Operating System is preferred.

3 System RAM DDR2 memory with ECC at least 16 GB per processor upgradable to 512 GB memory for whole system




4 HDD

Minimum 2X 146 GB hot plug SAS/ FC drive, scalable to 4 drives within the box support Raid 1,0. The HDD shall be sized for swap / virtual memory area of 3.5 times of main memory and OS.

5 System and CPU

Bidder to specify Number of CPUs in the offered solution to meet the desired performance level. 64 Bit RISC/Itanium, Symmetric Multi-Processor CPUs to be provided

6 CPU Clock Speed 1.2 GHz (minimum)

7 DVD drive per server 1 Number

8 Network Interface

Minimum 4 numbers of Gigabit Ethernet ports (100/1000 Mbps) based on latest PCI-e per server, in automatic fail-over / redundant configuration and auto-switching mode (In addition to those required for establishing cluster ) two copper and two Gigabit FibreSx autosensing port to be provided. This 4 NIC cards should operate in load sharing mode / hot standby mode to dual network

9 Scalability

The system shall be horizontally or Vertically scalable (by using the same type of processors as offered) twice of its capacity without IVL clearance for each machine. Expandability with respect to additional RAM : Not less than 2 times of the offered capacity

10 Other Parameters

The offered system should be Partitionable to 2 (Two) to 4 (four) Partitions. Each partition should be capable of booting different instances of Operating system and have identified separate I/O sub systems.

11 Disk Management Software

Suitable disk management software shall be supplied including Volume Manager to dynamically manage the logical volumes

12 Compiler Minimum one license per server of C Compiler & Development Package and C++ Compiler & Development Package to be provided




13 Rack Configuration

The servers shall be offered in rack mountable configuration, mounted in 19” 41/42 U OEM racks. The server shall be of 2U form factor

14 Power Supply Each server shall be provided with N+1 Power supply hot swappable

15 Fans Shoul d be Redundant hot swappable

16 Centralized management Solution

Central management solution shall be offered per rack, common to all the servers in the rack with 17” LCD TFT display, Keyboard and mouse

17 RAID CONTROLLER

Dual/Dual channel hardware RAID Controllers at 320 MBPS or better and Integrated RAID 0, 1, It should not occupy PCI slot

18 High Availability

The database Servers should be in clustered fail-over mode and application servers shall be in scale-out mode.

19 Server OEM

Server OEMs must be member of Transaction Processing Council (TPC) or Standard Performance Evaluation Council (SPEC)



Technical Specification -3Ph 4 wire whole Current Meter (see attachment no-1)



Technical Specification -3Ph 4 wire LT CT operated & HT CT/PT operated Meter (see attachment no-2)



Technical Specification -Service Cable LT PVC (see attachment no-3)



Section 9: Bill of Material

S. No. Item Name Description Unit Quantity

1

DLMS Compliant Poly Phase (three phase-whole current) Meters for 10 KW to 20KW Connections

Inclusive of all necessary accessories Number 62933

2 DLMS Compliant LT-CT Meters for above 20KW Connections and Distribution Transformers

Meters inclusive of all necessary accessories except appropriate ratio of CT unit & meter box

Number 12560

2.1 DT Meters with all necessary accessories with Meter Box, CT unit.

Number 1852

3 Meter Box for Poly –Phase (three phase-whole current) Meters

Inclusive of all necessary accessories Number 62933

4 Meter Box for DT Meters Inclusive of all necessary accessories Number 1852

4 GPRS Based AMR Modems

Inclusive of all necessary accessories and Antenna Number 85567

5 Desktops With Latest Microsoft Operating System and MS Office

Number 20

6 AMR Database Servers Number 2

7 AMR Application Servers Number 2

8 Testing, Quality and Development Environment Servers

Only for Data Center Location Number 2



S. No. Item Name Description Unit Quantity

9 AMR based Meter Data Acquisition & Analysis Software

Enterprise Level License for complete DHBVN Number 1

10 Software License - Server OS For Servers Number As Required

11 Software License – Databases

For AMR Servers, Testing, Quality and Development Environment

Number As Required

12 Floor Mount Racks for Servers Number As Required

13 M2M Gateway / Network Router

As per solution Requirement Number As Required

14 SAN Storage Minimum Requirement SAN Size (in TB) 20

15 Fiber Channel SAN Switch Specification as per solution requirement. Nos. 2

16

Network Bandwidth for Data Communication Between Meter’s Modem and Data Center

Minimum Primary Linkage For 5 years 4 MB

100% similar quantity of IT Hardware and Software are required to be supplied for Disaster Recovery Center. The quantity of servers and capacity of storage devices mentioned in the above BOM are indicative & are minimum and as per the design envisaged by DHBVN. The vendor may re-structure the same as per the requirement of the system / solution being proposed.



Section 10: Service Level Agreements

KPI No. KPI KPI Description Period Of

Measure Service Level Validation Penalty

1 Billing Data

Transfer/Submission of required meter data to DHBVN Billing System for raising bills against consumers before 24 hours of the billing schedule on Monthly Basis

Number of Consumers 100%

All the required meter data for billing should be available on time. (Monthly Status Report)

1% of Quarterly Fee of O&M Phase for each 1% below 100%.

2

Timely Submission of Data Analysis Reports

Submission of Data Analysis Reports of all connections by 5th

Timely Submission

of next month.

100%

Data Analysis Reports should cover all the connections and should analyze on all defined logics

1% of Quarterly Fee of O&M Phase for each one week delay.

3

Data Analysis for all Connections

Submission of Data Analysis Reports of all connections by 5th

Number of Connections

of next month.

100%

Data Analysis Reports should cover all the connections and should analyze on all defined logics






4 MIS Support

Submission of MIS / other reports required by DHBVN from time to time

Timely Submission 100%

Accurate and timely data availability.

0.5% of Quarterly Fee of O&M Phase for each 1% below 100%.

5 Project Management

Submission of Monthly Project Status Reports & Conducting Status meetings

Timely 100%

Accurate and timely data availability


6 Helpdesk

Resolution of ticket logged as per the Severity definition chart

Timely 99%

Reports generated from Ticket logging system


7

Uptime of all Servers and Networking Devices at Data Center

Uptime of Application and Database Servers and Networking Devices

Monthly 99.9% Monthly Status Report

1% of Quarterly Fee of O&M Phase for each 1% below 99.9%.

8

Backup/ Restore Management

The Supplier should take backup as per the backup schedule defined by utility

As per Schedule defined by DHBVN

99% Monthly Status Report






9 AMR Performance

Successfully Downloading of Data from AMR Nodes at first attempt

Number of connections 99%

Monthly Status Report


10 Data Consistency

Resolution of all Data Inconsistency related complaints within 24 Hours.

Per Month 100% Monthly Status Report

0.5% of Quarterly Fee of O&M Phase for each 1% below 100%

11

AMR Communication Devices (Modems) Performance

Resolution of all AMR Modems and associated Accessories related complaints within 24 Hours.

Per Month 100% Monthly Progress Report


12 Metering Performance

Resolution of all Meter Related Complaints within 24 Hours.



13 Communication Network Availability

Resolution of all Communication Failure Related Complaints within 8 Hours.







14

Server and DB Administration / Management

Rollout of patches (OS, infra level) on workstations and servers after patch being approved on test environment

Per Month 100% Patch Update Report


15

Network Monitoring and Management

Bidder to monitor the availability of the network link for 99.99% uptime and should measure link availability on a monthly basis

Per Month 99.99% Monthly Status Report


Service Level Agreement: - Selected Bidder will have to enter into Service Level Agreement (SLA) with DHBVN on non-Judicial Stamp Paper of DHBVN State to be known as “Service Level Agreement” setting out all terms & conditions including those mentioned in the terms & conditions for the proposed works. SLA Audit:-

A designated team/person from DHBVN or any third party auditor appointed by DHBVN, will review the performance of selected bidder against the SLA for each month or as per periodicity defined. The review/audit report will form the basis of any action relating to imposing penalty or breach of contract by selected bidder.

1. Purchaser shall issue a show cause notice to the Supplier.

Breach of SLA

In case the Supplier does not meet the service levels mentioned in this document, for three (3) continuous time-periods as specified in the relevant clause, the Purchaser will treat it as a case of breach of Service Level Agreement. The following steps will be taken in such a case:-

2. Supplier should reply against the notice within three working days.

3. If the Purchaser authorities are not satisfied with the reply, the Purchaser will initiate termination process as per GCC.



Section 11: Estimated Man-Power Requirements

The Bidder must demonstrate that it will deploy the following personnel (at least) for the key positions having academic qualification and experience as per the details noted there against:-

S. No. Position Nos.

Total Work Experience (years)

Experience in Similar Works (years)

1 Project Manager (B.Tech/Electrical/Electronics & Communication)

1 15 5

2 Assistant Project Managers (B.E/ B.Tech/Electrical/Electronics & Communication)

2 10 4

3 Site Engineers (B.E/B.Tech/Electrical/Electronics & Communication)

4 7 2

The Bidder shall provide details of the proposed personnel and their experience records in the relevant Forms included in Section IV, Bidding Forms. Experience Description

1. Project Manager

a) Project Manager should have Bachelor’s Degree in Engineering with Electrical or Electronics & Communication as specialization from a Recognized & Reputed Institute/University.

b) He should have 15years of post Qualification total experience. c) He should have at least 5 years of experience in Energy Metering system with

AMR/AMI application with following expertise areas: - Design / Implementation / O&M of AMR/AMI - Energy Meter (3PH LT/3PH HT) Installation - Energy Meter (3PH LT/3PH HT) Testing - Networking - Communication - Training - Knowledge of Project Monitoring tools like MS Project, Primavera

2. Assistant Project Manager

a. Assistant Project Manager should have Bachelor’s Degree in Engineering with Electrical or Electronics & Communication as specialization from a Recognized & Reputed Institute/University.

b. He should have 10years of post Qualification total experience. c. He should have at least 4 years of experience in metering system with AMR/AMI



application in Power Distribution System.

- AMR/AMI Application Implementation - AMR/AMI Application Testing - Energy Meter (3PH LT/3PH HT) Installation - Energy Meter Testing - Communication (GPRS/CDMA/PLC) - Modem installation & trouble shooting - Training - Knowledge of Project Monitoring tools like MS Project, Primavera

3. Site Engineer

a. Site Engineer should have Bachelor’s Degree in Engineering with Electrical or Electronics & Communication as specialization from a Recognized & Reputed Institute/University.

b. He should have 7years of post Qualification total experience. c. He should have at least 2years of experience in metering system with AMR/AMI

application in Power Distribution System.

- Energy Meter (3PH LT/3PH HT) Installation - Energy Meter (3PH LT/3PH HT) Testing - Modem installation & trouble shooting - Energy Meter Installation Quality Assurance System - Energy Meter data downloading, analysis and MIS Preparation - Knowledge of Project Monitoring tools like MS Project, Primavera

4.

Deployed Key Personnel can be replaced from the assignment only with a person of similar/higher experience and qualification subject to approval of DHBVN.



Section 12: Estimated Timelines Requirements

The bidder is expected to complete the Enterprise Wide - implementation of AMR system on all

the envisaged connections within 18 months from the date of award of contract by the DHBVN.

Selected bidder shall adopt the approach of dividing all connections in different lots of equal

quantities e.g. 15,000 (say) and then subsequently covering each 15,000 nodes for metering and

AMR system.

Bidder shall submit a detail Gantt chart along with the following implementation schedule.

Bidders shall drill down these activities into sub activities in the chart. The chart shall also detail

out time and resource effort required to execute each activity. The detailed bar charts for all the

work activities shall, however, be discussed and agreed to by the successful Bidder with the

owner before start of the execution of work.

Star

t Dat

e W

eekl

y Pl

an

End

Dat

e

Sr. No Activity Name W

1

W2

W3

W4

W5

……

1 Resource Mobilization and establishment of site office

2 System Design and approval from Owner

3 Proof of concept of the Overall Solution

4 Establishment of IT Infrastructure and MDAS

5 AMR for first 15000 Meters (Ph-1) 6 AMR for next 15000 Meters (Ph-2)

7 AMR for next 15000 Meters (Ph-3)




11 Operation and Maintenance Services



General Terms and Conditions of Payment Schedule 1. Selected Bidder needs to ensure completion of all works for a Lot before submitting the

invoice. Execution of activities includes supply of required hardware, software, customization, installation and commissioning. In addition, others activities like field survey, integration of identified legacy systems etc. shall also be completed. Payments shall be made lot wise and approved only after the entire scope of work for a lot is completed. In case even part of the work is pending (applications or hardware or networking etc.), payment for that lot shall not be made.

2. In case go-live of project is delayed, the entire cost and/or time over-run shall be the responsibility of the Supplier and shall be borne by him only.

3. Power to withhold: Notwithstanding anything contained in the payment schedule mentioned

above, if in the opinion of the Purchaser, any work done or supply made or service rendered by Supplier is deficient in any manner in comparison to the prescribed standards, Purchaser shall be at liberty to withhold a reasonable portion of the payments due to the Supplier, till such work/ supply/ service is made conforming to the prescribed standards. These powers to withhold payments shall be without prejudice to any other power/ right of the purchaser under this contract.

4. All payments for Operation and Maintenance Services (FMS) shall only be made after

submission of the Audit reports (in original) which shall be submitted by the Supplier along with the invoices and acceptance of the same by the Purchaser.

5. Payments made under the Contract shall be approved by the World bank in accordance with

the terms and conditions of the financing agreement between the Purchaser and the World Bank, and will be subject in all respects to the terms and conditions of that financing/Loan Agreement.

6. Selected Bidder should obtain completion certificate for each milestone from the utility and

raise an invoice against the same.

7. Operational and Maintenance Services: Cost for support and maintenance will be payable quarterly during the 5 years support and maintenance period from the date of “Enterprise wide rollout – go live date”. Quarterly installments will be 1/20th

of the total O&M cost. Payments will be subject to the Audit reports for that quarter.



Form ELI 1.1

Bidder Information Sheet

Date: ______________________

ICB No.: WB/DH/2013/G-04

Invitation for Bid No.: ________

Page ________ of _______ pages

1. Bidder’s Legal Name

2. In case of JVA, legal name of each party:

3. Bidder’s actual or intended Country of Registration:

4. Bidder’s Year of Registration:

5. Bidder’s Legal Address in Country of Registration: 6. Bidder’s Authorized Representative Information Name: Address: Telephone/Fax numbers: Email Address: 7. Attached are copies of original documents of:

• Articles of Incorporation or Registration of firm named in 1, above, in accordance with ITB Sub-Clauses 4.1 and 4.2.

• In case of JVA, letter of intent to form JVA including a draft agreement, or JVA agreement, in accordance with ITB Sub-Clauses 4.1 and 11.1(i) Single Stage Bidding or 11.1(g) Two Stage Bidding.

• In case of government owned entity from the Employer’s country, documents establishing legal and financial autonomy and compliance with the principles of commercial law, in accordance with ITB Sub-Clause 4.5.

Please note that a written authorization needs to be attached to this sheet as required by ITB 21.2 Single Stage Bidding) or ITB 17.2 Two Stage Bidding



Form ELI 1.2

Party to JVA Information Sheet

Date: ______________________


Invitation for Bid No.:_________

Page ________ of_ ______ pages

1. Bidder’s Legal Name:

2. JVA’s Party legal name:

3. JVA’s Party Country of Registration:

4. JVA’s Party Year of Registration:

5. JVA’s Party Legal Address in Country of Registration:

6. JVA’s Party Authorized Representative Information Name: Address: Telephone/Fax numbers: Email Address:

7. Attached are copies of original documents of:

• Articles of Incorporation or Registration of firm named in 1, above, in accordance with ITB Sub-Clauses 4.1 and 4.2.

• In case of government owned entity from the Purchaser’s country, documents establishing legal and financial autonomy and compliance with the principles of commercial law, in accordance with ITB Sub-Clause 4.5.



Form CON – 2

Historical Contract Non-Performance In case a prequalification process was conducted this form should be used only if the information submitted at the time of prequalification requires updating

Bidder’s Legal Name: _______________________ Date: _____________________

JVA Partner Legal Name: _______________________ ___________________


Page _______ of _______ pages

Non-Performing Contracts in accordance with Section III, Evaluation Criteria

�Contract non-performance did not occur during the stipulated period, in accordance with Sub- clause 6 of Section-3.

Pending Litigation, in accordance with Section III, Evaluation Criteria

�No pending litigation in accordance with Sub- clause 7 of Section-3

� Pending litigation in accordance with Sub- clause 7 of Section-3, as indicated below Year Outcome as

Percent of Total Assets

Contract Identification

Total Contract Amount (current value, US$ equivalent)

______

______

Contract Identification: Name of Employer: Address of Employer: Matter in dispute:

___________

______

______

Contract Identification: Name of Employer: Address of Employer: Matter in dispute:

___________



Current Contract Commitments / Works in Progress

Form CCC

Bidders and each partner to a JVA should provide information on their current commitments on all contracts that have been awarded, or for which a letter of intent or acceptance has been received, or for contracts approaching completion, but for which an unqualified, full completion certificate has yet to be issued.

Name of contract

Employer, contact

address/tel/fax

Value of outstanding work

(current US$ equivalent)

Estimated completion date

Average monthly invoicing over last

six months (US$/month)

1.

2.

3.

4.

5.

etc.



Form FIN – 3.1

Financial Situation

Historical Financial Performance

Bidder’s Legal Name: _______________________ Date: _____________________

JVA Partner Legal Name: _______________________ ICB No.: WB/DH/2013/G-04

Page _______ of _______ pages

To be completed by the Bidder and, if JVA, by each partner

Financial information in US$ equivalent

Historic information for previous ______ (__) years (US$ equivalent in 000s)

Year 1 Year 2 Year 3 Year … Year n Avg. Avg. Ratio Information from Balance Sheet Total Assets (TA)

Total Liabilities (TL)

Net Worth (NW)

Current Assets (CA)

Current Liabilities (CL)

Information from Income Statement Total Revenue (TR)

Profits Before Taxes (PBT)



Attached are copies of financial statements (balance sheets, including all related notes, and income statements) for the years required above complying with the following conditions:

• Must reflect the financial situation of the Bidder or partner to a JVA, and not sister or parent companies

• Historic financial statements must be audited by a certified accountant • Historic financial statements must be complete, including all notes to the financial statements • Historic financial statements must correspond to accounting periods already completed and

audited (no statements for partial periods shall be requested or accepted)



Form FIN – 3.2

Average Annual Turnover Bidder’s Legal Name: ___________________________ Date: _____________________

JVA Partner Legal Name: ____________________________ ICB No.: WB/DH/2013/G-04

Page _______ of _______ pages

Annual turnover data (construction only)

Year Amount and Currency US$ equivalent

_________________________________________ ____________________

_________________________________________ ____________________

_________________________________________ ____________________

_________________________________________ ____________________

_________________________________________ ____________________

*Average Annual Construction Turnover

_________________________________________ ____________________

*Average annual turnover calculated as total certified payments received for work in progress or completed, divided by the number of years specified in Section- 3, Evaluation Criteria, sub clause-9.

Form FIN3.3



Financial Resources

Specify proposed sources of financing, such as liquid assets, unencumbered real assets, lines of credit, and other financial means, net of current commitments, available to meet the total construction cash flow demands of the subject contract or contracts as indicated in Section III, Evaluation and Qualification Criteria

Source of financing Amount (US$ equivalent)

1.

2.

3.

4.



Form EXP 1.4.1

Experience - General Experience Bidder’s Legal Name: ____________________________ Date: _____________________

JVA Partner Legal Name: ____________________________ ICB No.: WB/DH/2013/G-04

Page _______ of _______ pages

Starting Month / Year

Ending Month / Year

Years*

Contract Identification

Role of Bidder

______

______

Contract name: Brief Description of the Works performed by the Bidder: Name of Employer: Address:

_________

______

______


_________

______

______


_________

______

______


_________

______

______


_________

*List calendar year for years with contracts with at least nine (9) months activity per year starting with the earliest year



Form EXP – 1.4.2

Specific Experience Bidder’s Legal Name: ___________________________ Date: _____________________

JVA Partner Legal Name: _________________________ ICB No.: WB/DH/2013/G-04

Page _______ of _______ pages

Similar Contract Number: ___ of ___ required.

Information

Contract Identification _______________________________________

Award date

Completion date

_______________________________________

_______________________________________

Role in Contract � Contractor

� Management

Contractor

�Subcontract

or

Total contract amount ____________________________ US$_________

_

If partner in a JVA or subcontractor, specify participation of total contract amount

__________%

_____________

US$_______

Employer’s Name: _______________________________________

Address:

Telephone/fax number:

E-mail:

_______________________________________

_______________________________________

_______________________________________

_______________________________________



Form EXP – 1.4.2 - (cont.)

Specific Experience (cont.)

Bidder’s Legal Name: ___________________________ Page _______ of _______ pages

JVA Partner Legal Name: ___________________________

Similar Contract No. __[insert specific number] of [total number of contracts] ___ required

Information

Description of the similarity in accordance with clause 12 of section-3:

Amount _________________________________

Physical size _________________________________

Complexity _________________________________

Methods/Technology _________________________________

Physical Production Rate

_________________________________

C:\Users\ABC\Desktop\23.05.13\MM-AMR Docuemnts\Attachment- 1 TS Of Three Phase 4 Wire Whole Current Meters.Doc Page 1 of 25

Specification No. CSC- 48-R-III/DH/UH/P&D/2012-13

TECHNICAL SPECIFICATIONS

OF

WHOLE CURRENT A.C. THREE PHASE FOUR WIRES

L.T. STATIC ENERGY METER OF

ACCURACY CLASS 1.0(10-60A)

WITH COMMUNICATION FACILITY

Issue Month: December, 2012 Common Specifications Committee

(CSC approval date:-6.11.2012) UHBVN & DHBVN


TECHNICAL SPECIFICATIONS FOR WHOLE CURRENT A.C. THREE PHASE FOUR WIRES STATIC ENERGY METER OF ACCURACY CLASS 1.0(10-60A) WITH COMMUNICATION FACILITY 1. SCOPE

The specification covers the design, manufacturing, testing, supply of AC whole

current 3 phase 4 wire static watt hour meter for measurement of active

energy (kWh) with initial and sustained accuracy of class 1.0 for solidly earthed

system with balanced and unbalanced loads having power factor in the range of

zero to unity (Lagging/ Leading). The meters shall be DLMS compliant as per IS:15959,

Category “C”..

2. APPLICABLE STANDARDS Unless otherwise especially modified and to the extent so modified from these

specification, the meter shall comply with the latest version of IS-13779, IEC-62053-

21:2003 and CBI&P Technical report 88/1998(latest amendments). The Manufacturer

should have ISO 9000 or above certification

3. CLIMATIC CONDITIONS

The Static Energy Meter shall be suitable for satisfactorily working under the following climatic conditions: -

1. Max. ambient air temperature 600C

2. Min. ambient air temperature (-)50C

3. Average Daily Max. ambient temperature 400C

4. Max. yearly weighted average ambient temperature

320C

5. Max. altitude above mean sea level 1000 m

6. Minimum Relative Humidity (%age) 26

7. Max. Relative Humidity (%age) 95

8. Avg. No. of Rainy days/year 120

9. Avg. annual rainfall 900 mm

10. Maximum wind pressure 195 kg/m2

The meter shall be suitably designed and treated for normal life and

satisfactory operation under the hot and hazardous tropical climate conditions and shall be dust and vermin proof. All the parts and surface, which are subject to corrosion, shall either be made of such material or shall be provided with such protective finish which provides suitable protection to them from any injurious effect of excessive humidity.


4. RATINGS

The rating of kWh meter should be as follows:-

Supply voltage 3x240V AC (Phase to Neutral),415V AC (Between phases)

Current range(basic)Ib 10 A Max. current 600% of Basic Current =10amp. Current rating 10-60A Class of accuracy 1.0(No drift in tolerance of accuracy for 10 years) Starting current 0.2% of Basic Current at unity power factor Power factor range 0 to 1 (Lagging & Leading) Power loss As per ISS-13779 Resistance to surge voltage >6kV peak As per ISS-13779 1.2/50Micro sec. IEC-62053-21:2003/CBIP-88

Test voltage of 50Hz for 1 Min. 2kV rms Clock time accuracy +/- 5 ppm at 25°C Temperature rise As per ISS-13779 Power consumption by meter As per ISS-13779

5 SUPPLY SYSTEM

Supply Voltage 3x240V AC (Phase to Neutral), 415V AC (Between phases)

Voltage variation range -40% to +30% of Vref

Frequency 50Hz +/- 5%

Power Factor +1 to -1

Further to this, meter should remain functional at -40% of Vref with single phase

condition (when two phases are missing

6 QUANTITY TO BE MEASURED / MONITORED

The display order shall be:- 6.1 Default Display (Continuously on auto scroll).

6.1.1 Cumulative Active Energy kWh along with legend.

6.1.2 Current calendar MD in kW along with legend.

6.1.3 Cumulative Max Demand along with legend.

6.1.4 No of reset count along with legend. These parameters should be displayed on the LCD continuously for a

period of 15 seconds on Auto scroll. In case of power failure, the meter should display above parameters i.e. 6.1.1 to 6.1.4 with push button.

6.2 On Demand Display(with push button)

6.2.1 Internal diagnostics

6.2.2 Cumulative kWh

6.2.3 Date


6.2.4 Real Time

6.2.5 Current month MD in kW

6.2.6 Voltage phase wise

6.2.7 Current phase wise

6.2.8 Inst. Power

6.2.9 Cumulative Max Demand

6.2.10 MDI reset count

6.2.12 Last month MD in kW

6.2.13 Last month MD in kW occurrence Date

6.2.14 Last month MD in kW occurrence Time

6.2.15 Meter Serial Number

The meter’s display should return to default display mode (continues auto scroll) if

push button is not operated for more than 10 seconds.

7 Auto Display

The meter shall have LED/LCD backlit type electronic display with minimum six digits

with additional provision for legend. The decimal digit shall be clearly distinguished

from integral digit. The registered parameters i.e. the data stored in meter shall not be

lost/ effected in the event of power failure. The display shall also not be

effected by electric and magnetic disturbances. The meter shall have non volatile

memory (NVM) which does not need battery back up. The NVM shall have minimum

retention period 10 years. The minimum character dimension sha l l be 10mmx5mm.

Impulse Counter & Stepper Motor shall not be provided in the meter.

Default MD integration period will be 30 min.

7.1 Meter shall store MD integration period alongwith date and time at the end of

every integration period new MD shall be previous MD and store, whichever is higher

and the same shall be displayed.

7.2 MD shall be reset automatically at the defined date (or period) or through CMRI

manually as when required. The re-setting shall be automatic at the end of every

month i.e. 24 hours of last day of month. Twelve last M.D. values shall be stored in

the memory also with auto reset count in numbers and reset count show on the

display. In addition to this the cumulative kWh should also be stored in the memory at

0-00 hrs. at the end of every month and show on the display . The meter should be

capable of storing last 12 month data with an option to retrieve the same.


7.3 Manual MD resetting should be possible. Use of scalable push button or any other

method is optional. 7.4 BILLING DATA

7.4.1 Meter serial number, Date and time, kWh, MD in kW, History of kWh & MD for

last 6 months along with TOD readings. TOD zone is as under:-

(i) 5.30 Hrs to 8.00 Hrs. (ii) 8.00 Hrs to 18.00 Hrs. (iii) 18.00 Hrs to 22.00 Hrs. (iv) 22.00 Hrs to 5.30 Hrs.

7.4.2 All the above parameters (namely kWh, MD in kW) are meter readings.

7.4.3 All these data shall be accessible for reading, recording and spot billing

by downloading through optical port on MRI or Laptop computers at site.

8 STARTING CURRENT: The starting current of the meter shall be 0.2% lb at unity power factor.

9 RUNNING AT NO LOAD:

The meter should comply with the requirements of IEC 1036/IS-13779 and CBIP

Technical Report 88/1998 (Latest amendment).

10 ACCURACY & LIMITS OF ERRORS:

The error of meters shall not exceed the permissible limits per standard IS 13779

(latest version) and CBIP Technical Report 88/1998 (with latest amendment) for a

period of at least 10 years from the date of supply. In case any drift is notified which

is beyond the permissible limits, the bidder shall re-calibrate the mete for correct

accuracy and if re-calibration is not possible, the meter shall be replaced by a new

meter without any extra cost. 11 TEST OUTPUT DEVICE :

The meter shall have a test output device in the form of a pulse indicator accessible

from the front and capable of being monitored by suitable testing equipment.

12 TESTS: 12.1 TYPE TESTS & TEST CERTIFICATES:

Meters shall be fully type tested as per IS: 13779 (latest version). The type test

certificates shall be submitted along with the offer. Offer without Type Test Report

shall be liable for rejection. The Type test certificates shall not be more than 3 years


old. Test certificates of appropriate range shall be accepted. The type certificates shall

be from institutions as per Appendix ‘G’ of CBIP Technical report 88 (amended).

12.2 ROUTINE TESTS

The Acceptance and Routine tests shall be carried out as per latest version of IS-

13779. 12.3 EFFECT OF MAGNETIC FILED OF EXTERNAL ORIGIN.

The meter shall be provided with adequate magnetic shielding so that any external

magnetic field (AC electro-magnets/DC magnet) as per the value specify in CBIP

technical report-88 (with latest amendment) application on the meter shall not effect

the proper functioning and recoding of energy as per error limits prescribed by CBIP.

However, the test certificates of the designed meter for AC abnormal magnetic field

& DC abnormal magnetic field as per clause 5.6.2 of CBIP -88 report (with latest

version). The required test certificate for the design rating of meter from NABL

accredited laboratory shall be submitted by the bidders along with the bid.

12.4 D.C IMMUNITY TEST

The meter should comply with the requirements of IEC 1036/IS-13779 and CBIP

Technical Report 88/1998 (Latest amendment).

12.5 INFLUENCE QUANTITIES

The meter shall work satisfactorily with guaranteed accuracy as per limit of IS 13779

and CBIP Technical Report 88/1988 (with latest amendments)under presence of the

following quantities:

12.5.1 External Magnetic field 0.5 Tesla. 12.5.2 Electro Magnetic Field. 12.5.3 Radio Frequency interference. 12.5.4 Vibration. 12.5.5 Harmonic wave form. 12.5.6 Voltage fluctuation. 12.5.7 Electromagnetic high frequency field. 12.6 ELECTROMAGNETIC COMPATIBILITY

The meter shall conform to provision as per IS-13779 and IEC-62053-21:2003

and CBIP Technical Report 88/1998 (Latest Amendments) and should be

protected against radiated interference from either magnetic or radio frequency

sources. The meter shall also withstand DC immunity test so as to ensure that the

meter does not saturate on passage of direct current.


12.7 METER POWER SUPPLY The meter should withstand the maximum system voltage i.e. 498 volts continuously.

In case of failure of power supply, the meter should display the measured quantities

minimum for 24 hours. This event will be logged in the history as power failure

(Indicating time, date & duration).

13 CONSTRUCTION 13.1 METER CASE & COVER

The meter case & cover will be ultrasonically welded with two no. polycarbonate

seals, one each on either side, so that Meter’s internal parts are only accessible

after breaking seals, ultrasonic welding case/cover of the meter and it should

become unserviceable. The meter base can be opaque and meter cover will be

Transparent or translucent with transparent window.

13.1.1 The supplier should indicate hardness, melting temperature and tensile yield strength

of the material and necessary test certificates of the same shall be furnished. The

meter case and transparent cover should be sturdy enough to prevent damage

during transportation and installation.

13.1.2 The meter chamber shall conform to the degree of protection IP 51 of IS: 12063/

IEC: 529 for protection against ingress of dust and moisture.

13.1.3 The polycarbonate plastic housing used may be provided with a key hole on the

top for fixing which should not be accessible to the consumer after terminal cover is

sealed.

The polycarbonate plastic used shall conform to ISS: 11731 besides meeting the test

requirement of heat reflection test as per ISO-75 and Glow wire test as per IS:

11000 (part 2/SEC-I) 1984 OR IEC PUB, 60695-2-12, Ball pressure test as per IEC-

60695-2-12 and Flammability Test as per IS 11731 (Part-2) 1986.

Plastic grade for Meter case should be LEXAN 500R and for meter cover should be

LAXAN 143R/940A. Even Bayer make polymer may be accepted.

13.2 TERMINAL BLOCK & COVER

The terminals may be grouped in a terminal block having adequate insulating

properties and mechanical strength. The terminal block shall be made from

best quality non-hygroscopic, flame retardant material (capable of passing the

flammability tests given in IS-11731) with nickel-plated brass for connecting

terminals. The clamping screw should be provided inside the terminal cover


and should have metallic sleeve molded within the block to avoid damage during

tightening of the screws.

The terminals in the terminal block shall be of adequate length in order to have proper

grip of conductor with the help of two screws through assembly of a plate so as to

make cage type arrangement. The screws shall have thread size not less than M4

and head having 4 -6 mm diameter. The screw shall not have pointed ends at

the end of threads. All terminals and connecting screws and washers should be of

tinned/nickel plated brass material.

The internal diameter of terminal hole shall be min. 8.5 mm and should comfortable

accommodate the 25 mm2 cable conductors. Normally the cable used in such meters

is 6 mm2 & 10 mm2 however at some places 25 mm2 can be used. The holes in the

insulating material shall be of sufficient size to accommodate the insulation of

conductor also.

The terminal cover shall be polycarbonate plastic with minimum thickness 2.0mm mm

and the terminal cover shall be of extended type completely covering the

terminal block and fixing holes except for the provision of conductor entry at the

bottom for incoming and outgoing leads. The terminal cover shall be so

provided that it remains permanently connected with meter base. The supplier

shall suitably design the cover, so that it opens and closes like a hinged door

and the ends of hinged pins shall be flattened so that it does not come out.

Provision for Minimum one number utility seal(s) as the terminal cover shall be made.

Supply voltage circuit is to be connected solidly from inside.

Plastic grade for Meter terminals should be LEXAN 500R and for meter terminal

cover should be LAXAN 143R/940A. Even Bayer make polymer may be accepted

13.3 DESIGN Voltage circuit, sealing arrangement, terminal block, terminal cover and nameplate

etc. shall be in accordance with IS-13779 (latest version).The meter shall be

compact and reliable in design, easy to transport and immune to vibration and

stock involved in transportation and handling. The construction of the meter shall

ensure consistent performance under all conditions especially during dust

storm/heavy rains/very hot weather. The insulating material used in the meter should

be non-hygroscopic, non-aging and of tested quality. The meter should be sealed

in such a way that the internal parts of the meter are inaccessible.


Further meter shall withstand an insulation test of 4 kV and impulse test at 8kV

& the terminal block and meter case shall have safety against spread of fire.

They shall not get ignited by thermal overload of live parts in contact with them as

per the relevant IS-13779

13.4 CIRCUITARY:

The meter shall have an operational indication device such as blinking LED given

type indication. The following indications are mandatory:

13.4.1 Meter Calibration (LED). 13.4.2 Phase available indication (LCD/LED). 13.4.3 Load Earthling (LED/ LCD).

13.4.4 Current reversal (LCD). 13.4.5 Magnet tamper (icon on LCD/LED).

The operation indicator should be accessible from the front. The mounting of components on

the PCB (Printed Circuit Board) shall preferably be SMT (Surface Mounted

Technology) type. The Electronic Components used in the meter shall be of high

quality and there shall be no drift in the accuracy of the meter at least upto10 years.

The circuitry in the meter shall be compatible with 2x8 bit (or better) processor and

the meter shall be based on digital measuring and sampling technique.

13.5 CURRENT & PRESSURE COILS

13.5.1 Current Circuit As per IS- 13779

13.5.2 Potential Circuit As per IS-13779. i.e Voltage Circuit

13.6 FIXING ARRANGEMENT

Every meter shall have three fixing holes one at the top and two at the bottom. The

top hole shall be provided with a special clip at the back of the mater so that

holding screw is not accessible to the consumer after the fixing of the meters. The

lower fixing screws shall be provided under the sealed terminal cover. The requisite

fixing screws shall be supplied with each meter.

13.7 SEALING:

Minimum 2 No. holes shall be provided for proper fixing of meter cover with 2 No.

polycarbonate numbered seals, of good quality, on opposite side (one by the meter

manufacturer and the other by the Utility/ Nigam on both opposite side.) So that

meter internal parts are accessible only after breaking the seals, ultrasonic welding

of case/cover of the meter.

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13.8 ELECTRONIC COMPONENTS

The meter shall be from high accuracy and reliable Surface Mount Technology (SMT) components. The supplier should submit the details of source/agencies from whom purchase of various components of meters used by them, has been done, to the authorized representative/ team deputed by Nigam for its verification. The make of components used in the meter should be used as listed below. Sr. No.

Component Function

Requirement Makes and Origin

1. Measurement or computing chips

The Measurement or computing chips in the meter should be with the Surface mount type along with ASICs.

USA: Anolog Devices, Cyrus, ST, Teridian, Motorola, Renasas Logic,Atmel,Phillips, Texas Instruments. South Africa: SAMES Japan: Hitachi or Oki Free scale semiconductors, MMI, Maxim, Siemens

2. Memory Chip The memory chips should not be affected by the external parameters like sparking high voltage spikes or electrostatic discharges.

USA Atmel,National Semiconductors,Texas Instruments,Phillips,ST, Renasas Japan: Hitachi or Oki Microchip, Ramtron/ Numonyx, Siemens

3. Display modules

a) The display modules should be well protected from the external UV radiations. b) The display visibility should be sufficient to read the Meter mounted at height at 0.5 meter as well as at the height of 0.2 meters (ref 3.2d for Viewing angle). c) The construction of the modules should be such that the displayed quantity should not disturbed with the life of display (PIN Type) d) It should be trans reflective HTN or STN type industrial grade with extended temperature range.

Any Reputed Manufacturer

4. Communication modules

Communication modules should be compatible for the RS 232 ports.

USA: National Semiconductors, HP, Ontonica, ST Holland/Korea: Philips Japan: Hitachi Taiwan:Ligitek Germany: Siemens Everlight


5. Optical Port Optical Port should be used to transfer the meter data to meter reading instrument. The mechanical Construction of the port should be such to facilitate the data transfer easily.

USA: National Semiconductors, HP, Holland/Korea: Philips Japan: Hitachi Taiwan:Ligitek Osram, Everlight, EG &G VATEC

6. Power Supply The power supply should be with the capabilities as per the relevant standards. The power supply unit of the meter should not be affected. In case the maximum voltage of the system appears to the terminals due to faults or due to wrong connections.

SMPS / Capacitor type

7. Electronic Components

The active & passive components should be of the surface mount type & are to handled & soldered by the state of art assembly processes.

USA: National Semiconductors, Atmel, Philips, Texas Instruments, Texas, ST, Onsemi Japan: Hitachi, Oki, AVX or Ricoh Korea: Samsung

8. Mechanical Parts

a) The internal electrical component should be of electrolytic copper & should be protected from corrosion, rust etc.

b) The other mechanical components should be protected from rust, corrosion etc. by suitable plating /painting methods.

9. Battery Lithium with guaranteed life of 10 years.

Verta, Tedirun, Sanyo or National Renota, Panasonic, ST, Epson, Maxell, Intersil 10. RTC & Micro

controller The accuracy of RTC shall be as per relevant IEC/IS standards

USA: Philips, Dallas, Atmel, Motorola, Microchip Japan: NEC or Oki Texas instruments, ST, Epson, Intersil, Renasas

11. P.C.B. Glass Epoxy, fire resistant grade FR4, with minimum thickness 1.6mm

(BBT test is must)

No components of any other make other than mentioned above shall be accepted.

13.9 SOFTWARE & COMMUNICATION COMPATIBILITY 13.9.1 The optical port shall be compatible to RS-232. Communication modules should be

RS-232 optical port (for communication with meter reading instruments &


communication with various modems for AMR). The RS-232 port shall be capable to

transfer the data locally i.e. through CMRI, Laptop etc. & transfer the data to the

remote end through GPRS/GSM/any other technology to the main computer /Laptop

by using Modem. Half-meter long cable, of suitable size, having facility at one end,

for connecting to the optical port, other end shall be provided with RS – 232

Connector, as spare cable, so that the optical port can be brought out from the

meter box. The meter shall have necessary facilities to transfer the data via the

Communication port, the Hand Held Data Collection Device (DCD) and to the computer

at remote end to get complete details in alpha-numeric form. The necessary software for

this purpose shall be provided by the supplier. The Meters shall be compatible to

AMR. One additional port i.e. RJ11 should also be provided.

13.9.2 The Supplier shall supply Software required for CMRI & for connectivity to AMR

modules. The supplier shall also provide training for the use of software. The

software should be compatible to Microsoft Windows systems (Latest version). The

software should have polling feature with optional selection of parameters to be

down loaded for AMR application.

13.9.3 Necessary provision shall be made in the software for converting all the

parameters available for new and old meters if supplied earlier. Copy of operation

manual shall be supplied.

13.9.4 The Meter shall support a minimum baud rate of 9600 on optical port as well as RS

232 remote communication port. It shall be possible to read data set from the meter

from both ports simultaneously,

13.9.5 Meter shall support the DLMS open protocol (IS 15959) for communication. Apart

from this, parameters which are not covered in companion standard; should be

available in meter with manufacture specific implementation. Manufacturer specific

BCS should have capability to show all parameters which are covered in

specification.

14 PACKING

The meters shall be suitably packed for vertical/horizontal support to withstand

handling during transport. The bidder shall be responsible for any damage during

transit due to inadequate or improper packing.The meters shall preferably be

supplied in thermocol packing of minimum 10 mm thickness/ Corrugated (CFS) box

packing of min 3 mm thickness.


15 DESIGN LIFE

The meter shall have a design life of at least 10 years.

16 QUALITY ASSURANCE PLAN

The design life of the meter shall be minimum 10 years and to prove the design life,

the firm shall have at least the following Quality Assurance Plan:

16.1 The factory shall be completely dust proof.

16.2 The testing rooms shall be temperature and humidity controlled as per relevant

standard.

16.3 The testing and calibrating equipment should be automatic and all test equipment

shall have their valid calibration certificates.

16.4 Power supply used in testing equipment shall be distortion free with sinusoidal

wave-forms and maintaining constant voltage current and frequency as per the

relevant standards.

16.5 During the manufacturing of the meters the following checks shall be carried out:

16.5.1 Meter frame dimension tolerance shall be minimum.

16.5.2 The assembly of parts shall be done with the help of jigs and

fixtures so that human errors are eliminated.

16.5.3 The meters shall be batch tested on automatic, computerized test

bench and the results shall be printed directly without any human errors. 17 ANTI TAMPER FEATURES

The meter shall not be affected by any remote control device and shall continue

recording energy under any one or combinations of the following condition.

17.1 The meter shall record correctly irrespective of phase sequence and even in case

of current reversal and missing potential or Meter should record as per prevailing

electric connection.

Meter should not record forward energy under unbalance capacitive load condition

only. Further, Meter should not log current reversal event under this condition.

17.2 The meter shall continue record energy;

17.2.1 In the event neutral to the meter is disconnected from both ends of the

meter and any phase is shorted to the neutral and supply is used

with earth from any phase, meter should record energy at Vref, Actual

Current and UPF on all phases only and log such event with date and


time. The Error shall be within ±3%. When all 3 phases remained

connected at their respective places.

17.2.2 Meter must function accurately, on all the phases individually

when single phase load is used with earth and neutral to the

meter is disconnected at the neutral point of the meter remaining

phases are connected at respective places under balance voltage

condition.

17.2.3 The meter shall keep working even in the presence of any two wires, i.e.

shall record consumption at Vref, actual current and UPF in absence of

neutral and any one phase or any two phases. The Error shall be within ±3%.

17.3 The meter shall be factory calibrated.

17.4 In the meters original software, there shall be no possibility of tampering

including viruses.

17.5 Meter shall record the energy accurately under the effect of radiation emitted by

mobile phone. The test shall be carried out by bringing a mobile phone in the

close proximity (almost touching the meter) of the meter for 10 minutes when

there is an incoming call ( ringing or being received ) and shall be checked under

the following condition:

17.5.1 10% Ib and UPF

17.5.2 50% Ib and UPF

17.5.3 Ib and UPF

17.5.4 Ib and 0.8 PF

17.5.5 120% Ib and UPF

17.6 The Meter shall be immune or shall log the event of attempt of tampering by the

external magnetic field with permanent magnet, occurrences & restoration with date

& time to the external magnetic field. The meter shall also start recording energy at

maximum current IMAX under such influence of abnormal magnetic field irrespective

of actual load. The meter shall record as per actual load once the external abnormal

magnetic field is removed.

17.7 Meter shall log & display tampers of

17.7.1 Potential Missing 17.7.2 Current circuit reversal 17.7.3 Current circuit short 17.7.4 Injecting AC/DC high frequency/Current signal in neutral.


17.8 Meter shall be immune of any abnormal frequency signal OR Meter shall log

& display at tamper in the event abnormal frequency signal i.e. less than

47.5Hz OR more than 52.5 Hz is supplied to the meter.

17.9 Load Survey-Load survey for all the billing parameters/Anti Tamper Features should be

available for 120 days.

17.10 Minimum 200 number of events (occurrences + restoration; occurrence &

restoration will be counted as separate events with date & time and voltage,

current & power factor of more than 10 minutes except Magnet , ND & Cover

open) shall be available in the meter memory on roll over facility. All the

information shall be available in a standard simple format.

17.11 Meter should register energy correctly as per prevailing IS at 240V and UPF even

with neutral disconnected or neutral available through by putting variable

resistance/capacitor/diode.

17.12 The meter shall work satisfactorily under presence of various influences

conditions like External Magnetic Field, Electromagnetic Field, Radio Frequency

Interference, Vibrations, harmonic Distortion, Voltage/Frequency

Fluctuations, and electromagnetic High Frequency Fields etc. The meter should

be immune to electrostatic discharges (generated by High Voltage/Frequency

Tamper device) of voltage up to 35 KV level (approx.).

To this effect a test certificate must submitted by the bidder from NABL

accredited laboratory as per following criteria:

The accuracy of the meter should not be affected with the application of abnormal

voltage / frequency generating device (having spark discharge of approximately

35kV) in any of the following manner for a total period of 10 minutes:

17.12.1 On phase or neutral terminals

17.12.2 On any connecting wires of the meter.

17.12.3 Voltage discharge with 0-10mm spark gap

17.12.4 Spark on meter body

17.12.5 At any place in load circuit

The accuracy of meter should be checked before, during & after the application of said devices and the accuracy of meter should not be affected.


17.13 Meter Body Opening:

The meter shall have provision for detection and logging of opening of meter cover.

Meter must detect/log with date and time meter body opening tamper, body

opening must also be logged in absence of power supply.

Separate legend for cover open event shall be made available on LCD. This legend shall

remain in on state till meter reading so that it will come in to notice of meter reader.

Cover open event should be part of non-roll over compartment so that first cover open

event information remain in meter.

However cover open count “date & time” should appear in auto mode as well as

push mode display.

18 NAME PLATE AND MARKING

18.1 Every meter shall have a name plate clearly visible and indelible and distinctly

marked in accordance with IS 13779 (latest version). The following information

should appear on an external plate attached to the meter cover:

18.1.1 Manufacturer’s name or trade mark and place of manufacture.

18.1.2 Designation of type.

18.1.3 Number of phases and number of wires for which the meter is suitable.

18.2 In addition to above, the following information shall be marked on a name plate

preferably placed with in the meter:

18.2.1 Sr. No. and year of manufacture

18.2.2 Principal unit in which the meter records.

18.2.3 Reference voltage.

18.2.4 Basic current and rated maximum current.

18.2.5 Reference frequency in Hz.

18.2.6 Meter constant.

18.2.7 Class index.

18.2.8 Reference temperature.

18.2.9 The words properties of ‘DHBVN’ or ‘UHBVN’ depending upon the

name of Nigam to whom meters are supplied.

18.2.10 BIS Mark.

18.2.11 Warranty 5 years

18.2.12 P.O. NO.& date


19 TESTING AND MANUFACTURING FACILITIES

The bidder shall have at least the following testing facilities to ensure accurate

calibration:

19.1 Insulation resistance measurement. 19.2 Running at no load. 19.3 Starting current test. 19.4 Limits of error. 19.5 Range of adjustment. 19.6 Power loss in voltage and current coil. 19.7 Repeatability of error. 19.8 Transportation test. 19.9 Low load run test. 19.10 Heating test. 19.11 Protection against water, dust and moisture. The meter shall confirm to the degree

of protection IP-51 against ingress of dust, moisture and vermin’s 19.12 Effect of Magnetic field of external origin as per clause 5.6.2 of CBIP Report-88

with latest amendments & provision of Nigam Technical Specification. 20 INSPECTION

20.1 All meters shall be duly tested and sealed by the firm at their premises prior to

inspection.

20.2 The Nigam Inspecting Officer will inspect double the number of meters as per

sampling plan of ISS 13779 (latest version). Max. size/ lot of 5,000 numbers shall

be considered for acceptance test as per ISS 13779. Higher lot shall be considered

as two or more lots. The inspecting agency can carry out any type test which felt

necessary as acceptance test at firm’s works. After testing, these sample meters

shall be additionally sealed by the inspecting officer and one copy of the

inspection report will be handed over to the manufacturer. The authorized inspecting

officer will send through manufacturer one sample of each successive lot (of 5000

meters) directly from firm’s works during inspection for Acceptance Tests and Anti

Tamper Features instead of all tests as per technical specification/ ISS from any

NABL lab.

20.3 The supplier shall submit the details of source/ agencies from whom purchase of

various components of meters used by them, has been done, to the authorized

representative/ team deputed by Nigam for its verification.

20.4 The manufacturer shall be liable to pay penalty of Rs 20,000/- for each

occasion at which the fake inspection call has been made. This penalty would be in


addition to the expenses incurred by the Nigam in deputing the Inspecting

Officer for carrying out such inspection.

In case the material offered for inspection fails in Ist inspection, the

Nigam will have the right to levy a penalty at 0.1 % of the order value. In case the

material offered for inspection fail during the 2nd inspection, the Nigam will have the

right to increase the penalty to 0.25% of the order value. In case, the material

offered fails during the 3rd

Upon the firm failing to do so, the damages / defects may be got rectified by the Nigam

and the cost adjusted from the firm’s pending dues and/or security deposit against this

and final inspection also, the firm will be liable for penal

action including forfeiture of EMD, risk purchase, debarring/ blacklisting in future

and no further opportunity for inspection would be provided to the supplier firm.

21 CHALLENGE CLAUSE: The material offered/received after the inspection by the authorized Inspecting Officer

may again be subjected to the test for losses or any other parameters from any testing

house/in house technique of the Nigam having requisite capabilities and facilities. The

results, if found deviating/ unacceptable or non-complying to approved GTPs the lot

shall be rejected and bidder shall arrange to supply the replacement within thirty (30)

days of such detection at his cost including to & fro transportation. In addition to this

penalty @10% of cost of the inspected lot of material shall be imposed.

22. GUARANTEE: The meter shall have a designed life of at least 10 years and the supplier shall be

responsible to replace, free of cost, with no transportation or insurance - cost to the

Nigam, up to destination, the whole or any part of the material which, under normal and

proper use, proves defective in quality or workmanship, subject to the condition that

the defect is noticed within 66 months from the date of receipt of material by the

consignee or 60 months from the date of installation, which ever period may expire

earlier. The consignee or any other officer of the Nigam, actually using the material, will

give prompt notice of each such defect to the supplier as well as the Purchasing

authority and the Controller of Stores. The replacement shall be affected by the

supplier within a reasonable time, but not, in any case, exceeding 45 days. The

supplier shall also arrange to remove the defective supply within reasonable period but

not exceeding 45 days from the date of issue of the notice in respect thereof. The

warranty for 60/66 months shall be one time.


or any other contract in force and the balance left be got deposited by the supplier. The

Nigam may withhold the amount, equal to cost of defective material. The purchaser

shall recover an equivalent amount plus 15% supervision charges, if the defective

material is not repaired / replaced with in the above specified period.

The cumulative damage rate during warrantee period should not exceed:-

i) Up to one year 3%

ii) Up to two years 4%

iii) Up to three years 5%

iv) More than four years 6%

If the supplier fails to adhere to the above requirement, the Nigam may take any penal

action against the supplier upto and including blacklisting.

23 ANNEXURES

The bidder shall submit the following Annexure (as per format) which are part and

parcel of the specification:

Annexure A Guaranteed and Technical particulars.

Annexure B Deviation from specifications.

Annexure C Deviations from specified standards.

Annexure D Deviations from specified test requirements.

Annexure E Bidder’s experience.

General Manager / P&D, Cum- Member Secretary,

UHBVN, Panchkula


ANNEXURE-A GUARANTEED TECHNICAL PARTICULARS FOR THREE PHASE WHOLE CURRENT STATIC ENERGY METER

Sr. No. DESCRIPTION AS OFFERED BY FIRM 1. Maker’s Name 2. Type of meter

i) Basic current (A) ii) Maximum current

3. Standards to which the meter conform 4. Overload capacity 5. Dynamic range 6. Power supply variation

i) Specified operational range ii) Limit rage of operation iii) Frequency

7. Accuracy class 8. P.F. Range 9. Variation of voltage at which meter functions normally 10. Power consumption per phase

i) Voltage circuit ii) Current circuit

11. Minimum starting current of the meter (% Ib ) 12. Impulse voltage 13. Display (No. of digits and character height) 14. Continuous display (Auto Display mode) 15. Operational indication-LED 16. a) Material for base/terminal block

b) Material for meter cover/terminal cover

17. a) Meter terminal block having sealable extended terminal cover. b) No of seals to be Provided. c) Connection diagram inside the terminal cover

18. Communication port. 19. REAL Time clock with back up battery Life of battery 20. Non volatile memory retention time in absence of power. 21. MD reset 22. Self diagnostic feature 23. Load survey 24. Snap shot facility 25. No. of tamper events 26. Temper persistence time 27. Routine tests 28. Acceptance tests 29. Type tests 30. Testing facilities 31. BIS license 32. ISO 9001/9002 33. Guarantee


DEVIATIONS FROM SPECIFICATIONS ANNEXURE-B

Sr. No. Specification

Clause No. Requirement of Deviation

Proposed Specification

Reasons for Deviation

1. Name of firm 2. Name & signature of tenderer 3. Designation 4. Dated


ANNEXURE-C

DEVIATIONS FROM SPECIFIED STANDARDS Sr. No. Particulars Stipulation of

Specified standard ………………. Standard Stipulation Ref.

Stipulation standard adopted By tenderer ……………… Standard stipulation

Ref.

Remarks



ANNEXURE-D

DEVIATIONS FROM SPECIFIED TEST REQUIREMENTS SPECIFIED IN RELEVANT & PRESENT SPECIFICATION

……………………………………………………………………………………………… Sr. No.

Name of test Standard No. & Clause No.

Requirement of standard

Proposed Deviation

Reasons for Deviations

……………………………………………………………………………………………… 1. Type test 2. Acceptance test



ANNEXURE-E

BIDDER’S EXPERIENCE ……………………………………………………………………………………………… Sr. P.O. with To whom Description Qty. Status of Remarks No. date Supplied of material P.O. ………………………………………………………………………………………………

1. Name of firm 2. Name & signature of

tenderer 3. Designation 4. Date

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Specification No. CSC-45/Rev-1 /DH/UH/P&D/2010-2011

TECHNICAL SPECIFCATION

FOR

3PHASE 4 WIRE CT/PT OPERATED FULLY STATIC AMR COMPATIBLE TRI-VECTOR ENERGY METERS

FOR

AREA RING FENCING, HT CONSUMERS/ FEEDER METER &

STATIC LT / CT OPERATED METERS

Issue Month: Common Specifications Committee UHBVN & DHBVN

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1.0 SCOPE

Design, manufacturing, testing, supply and delivery of AC, 3 Phase, 4 Wire, CT/PT operated fully Static and AMR compatible Tri-Vector Energy Meters for measurement of different electrical parameters listed elsewhere in the document including Active Energy (kWh), Reactive Energy (kVArh), Apparent Energy (KVAH) etc. The detail scope is given below.

2.0 APPLICATION a) As Boundary Meters for Ring fencing of an Area, b) In Substation on incoming/Outgoing HT feeders, c) On Distribution Transformers d) LT and HT Consumers 3.0 STANDARDS TO WHICH METERS SHALL COMPLY Guidelines on “Data Exchange for Electricity Meter Reading, Tariff and Load Control – Companion Specification”. IS: 14697 /1999 (reaffirmed 2004) Specification for AC Static Transformer operated Watt Hour & VAR-Hour meters (class 0.5S); IS-15707 Specification for Testing, evaluation, installation & maintenance of AC Electricity Meters-Code of Practice The equipment meeting with the requirements of other authoritative standards, which ensure equal or better quality than the standard mentioned above, also shall be considered; in case of conflict related with communication protocol, DOC No. ETD13.6211 dated April,2010 shall prevail upon The meters shall be DLMS compliant as per IS:15959. For conflict related with other parts of the specification, the order of priority shall be – i) This technical specification ii) IS: 14697 /1999 (reaffirmed 2004). 4. CLIMATIC CONDITIONS:-The Static Energy Meter shall be suitable for satisfactorily working under the following climatic conditions.

1. Max. ambient air temperature 600C

2. Min. ambient air temperature (-)50C

3. Average Daily Max. ambient temperature 400C

4. Max. yearly weighted average ambient temperature

320C

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5. Max. altitude above mean sea level 1000 m

6. Minimum Relative Humidity (%age) 26

7. Max. Relative Humidity (%age) 95

8. Avg. No. of Rainy days/year 120

9. Avg. annual rainfall 900 mm

10. Maximum wind pressure 195 kg/m2

5 GENERAL TECHNICAL REQUIREMENTS 1 TYPE AMR Compatible Static, 3 Ph, 4 Wire Tri-Vector Energy

Meter 2 FREQUENCY 50 Hz ±5% 3 ACCURACY

CLASS 0.5S

4 SECONDARY VOLTAGE

1.For CT/PT operated HT meters-Suitable for operation from 110V Ph-Ph or 63.5V Ph-N 2.For distribution transformer and other LTCT operated Meters- Suitable for operation from 415V Ph-Ph or 240 V Ph-N

5 BASIC CURRENT (Ib)

-/5 Amps. as per existing CT for -feeders

6 MAXIMUM CONTINUOUS CURRENT

2.0 Ib; Starting and Short time current shall be as per IS-14697

7 POWER CONSUMPTION

i) The active and apparent power consumption, in each voltage circuit, at reference voltage, reference temperature and reference frequency shall not exceed 1. 5 W and 8 VA.

ii) The apparent power taken by each current circuit, at basic current, reference frequency and reference temperature shall not exceed 1.0 VA

8 POWER FACTOR 0.0 Lag -Unity- 0.0 Lead 9 DESIGN Meter shall be designed with application specific integrated

circuit (ASIC) or micro controller; shall have no moving part; electronic components shall be assembled on printed circuit board using surface mounting technology; factory calibration using high accuracy (0.05 class) software based test bench.

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6.0. CONSTRUCTIONAL REQUIREMENT/ METER COVER & SEALING ARRANGEMENT

6.1 METER CASE: The meter case & cover will either be ultrasonically welded or shall

have push fit type arrangement with two no. polycarbonate seals, of good quality, one each on either side, so that meter’s internal parts are only accessible after breaking seals, ultrasonic welding, push fit arrangement or case cover of the meter and it should become unserviceable. The material for base and cover (transparent / translucent) of the meter shall be of Polycarbonate. The meter shall be factory calibrated and shall have unidirectional screws, fully embedded so that these cannot be unscrewed by means of pliers etc. for sealing. The meter case shall have at least three mounting holes. 2 holes for mounting screws, on the terminal block; sealed beneath the terminal cover and one for hanging screw on the top.

6.2 WINDOWS: -The meter cover shall be of Toughened Glass or Reinforced Polycarbonate

material with one window. The window shall be of transparent material, ultrasonically welded with meter cover / part & parcel of meter cover so that it cannot be removed undamaged; without breaking the meter cover.

6.3 TERMINALS AND TERMINAL BLOCK: The terminals may be grouped in a terminal

block having adequate insulating properties and mechanical strength. The terminal block shall be made from best quality non - hygroscopic, flame retardant material (capable of passing the flammability tests, as per IS -11731) with nickel-plated brass or aluminium alloy for connecting terminals. The clamping screw should be provided inside the terminal cover and should have metallic sleeve molded within the block to avoid damage during tightening of the screws. The terminals in the terminal block shall be of adequate length in order to have proper grip of conductor with the help of two screws through agency of a plate so as to made cage type arrangement. The manner of fixing the conductors to the terminals shall ensure adequate and durable contact such that there is no risk of loosening or undue heating. Screw Connections, transmitting contact force and screw fixing, which may be loosened and tightened several times during the life of the meter, shall screw into a meter nut. All parts of each terminal shall be such that the risk of corrosion, resulting from contact with any other meter part, is minimized. Two screws shall be provided in each current terminal for effectively clamping the external leads or thimbles. Each clamping screw shall engage at least 3 threads in the terminal. The ends of screws shall be such as not to pierce the conductor. Electrical connections shall be so designed that the contact pressure is not transmitted through insulating material. For current circuits, the voltage is considered to be the same as for the related voltage circuit. The internal diameter of terminal holes shall be 5.5mm (min.) The clearances and creep age distances shall confirm to clause 6.60 of IS: 13779 /1993.

It shall conform to IS 11731 (FH-1category) besides meeting the test requirement of heat deflection test as per ISO 75, glow wire test as per the IS:11000 (part 2/SEC-1) 1984 OR IEC PUB,60695-2-12, Ball pressure test as per IEC--60695-10-2 and Flammability Test As per UL 94 or As per IS 11731(Part-2) 1986

6.4 TERMINAL COVER:- The terminal cover shall be extended type, which can be sealed

independently of the meter cover. The terminal cover shall enclose the actual terminals; the conductor fixing screws, the external conductors and their insulation i.e. no part of

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meter or cable / accessories shall be visible from the front of the meter. When the meter is mounted, no access to the terminal shall be possible without breaking the seal (s) of the meter terminal cover. The terminal cover shall have at least two sealing screws. The fixing screws used on the terminal cover for fixing and sealing shall be kept captive in the terminal cover.

6.5 SEALING: - 2 no unidirectional sealing screw shall be provided for proper fixing of meter

cover with 2 no good quality polycarbonate seals, one each on either side, so that the meter internal parts are only accessible after breaking the seals, ultrasonic welding, push fit arrangement or case cover of the meter. Separate sealing arrangements shall be provided for MDI reset and communication port. In addition, the firm / supplier shall affix 2 no good quality, numbered hologram, on base and cover; one on each side and its record should be forwarded to the Nigam.

7.0 WORKING ENVIRONMENT

As per IS 14697-1999 (reaffirmed 2004). Meter to perform satisfactorily under Non-Air Conditioned environment (within stipulations of IS)

Meter body will conform to IP51 degree of protection. For outdoor use meter shall be installed in sealed enclosure conforming to IP 55. The meter shall be suitable designed for satisfactory operation under the hot and hazardous tropical climate conditions and shall be dust and vermin proof. All the parts and surface, which are subject to corrosion, shall either be made of such material or shall be provided with such protective finish, which provided suitable protection to them from any injurious effect of excessive humidity.

8.0 MANUFACTURING PROCESS, ASSEMBLY AND TESTING

Meters shall be manufactured using latest and ‘state of the art’ technology and methods prevalent in electronics industry. The meter shall be made from high accuracy and reliable surface mount technology (SMT) components. All inward flow of major components and sub assembly parts (CT, PT, RTCs/Crystal, LCDs, LEDs, power circuit electronic components etc.) shall have batch and source identification. Multilayer ‘PCB’ assembly with ‘PTH’ (Plated through Hole) using surface mounted component shall have adequate track clearance for power circuits. SMT component shall be assembled using automatic ‘pick-and-place’ machines, Reflow Soldering oven, for stabilized setting of the components on ‘PCB’. For soldered PCBs, cleaning and washing of cards, after wave soldering process is to be carried out as a standard practice. Assembly line of the manufacturing system shall have provision for testing of sub-assembled cards. Manual placing of components and soldering, to be minimized to items, which cannot be handled by automatic machine. Handling of ‘PCB’ with ICs/C-MOS components, to be restricted to bare minimum and precautions to prevent ‘ESD’ failure to be provided. Complete assembled and soldered PCB should undergo functional testing using computerized Automatic Test Equipment. Fully assembled and finished meter shall undergo ‘burn-in’ test process for 12 hrs at 55 degree Celsius (Max. temperature not to exceed 60 degree Celsius) under base current (Ib) load condition.

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Test points should be provided to check the performance of each block/stage of the meter circuitry. RTC shall be synchronized with NPL time at the time of manufacture. Meters testing at intermediate and final stage shall be carried out with testing instruments, duly calibrated with reference standard, with traceability of source and date.

9.0 DISPLAYS

The meter shall have 7 digits (with ±indication), parameter identifier, backlit Liquid Crystal Display (LCD) of minimum 10 mm height, wide viewing angle. Auto display cycling push button required with persistence time of 10 Seconds. LCD shall be suitable for temperature withstand of 70 deg C; Sequence of display of various instantaneous electrical parameters shall be as desired by Purchaser at the time of order.

The data stored in the meters shall not be lost in the event of power failure. The meter shall have Non Volatile Memory (NVM), which does not need any battery backup. The NVM shall have a minimum retention period of 10 years.

10.0 PERFORMANCE UNDER INFLUENCE QUANTITIES

The meters performance under influence quantities shall be governed by IS 14697-1999 (reaffirmed 2004). The accuracy of meter shall not exceed the permissible limits of accuracy as per standard IS: 14697 (latest version).

11.0 OUTPUT DEVICE

Energy Meter shall have test output, accessible from the front, and be capable of being monitored with suitable testing equipment while in operation at site. The operation indicator must be visible from the front and test output device shall be provided in the form of LED. Resolution of the test output device shall be sufficient to enable the starting current test in less than 10 minutes.

12.0 REAL TIME INTERNAL CLOCK (RTC)

RTC shall be pre-programmed for 30 Years Day/date without any necessity for correction. The maximum drift shall not exceed +/- 300 Seconds per year.

The clock day/date setting and synchronization shall only be possible through password/Key code command from one of the following:

a) Hand Held Unit (HHU) or Meter testing work bench and this shall need password enabling for meter;

b) From remote server through suitable communication network or Sub-station data logger ‘PC’.

13.0 QUANTITIES TO BE MEASURED & DISPLAYED

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The meter shall be capable of measuring and displaying the following electrical quantities within specified accuracy limits for polyphase balanced or unbalanced loads:

a) Instantaneous Parameters such as phase and line voltages, currents, power factors, overall kVA, kW, kVAr, power factor, frequency etc as per details given in the table below and enclosed annexure.

b) Block Load Profile Parameters such as kVAh/kWh/kVArh (lag/lead)/Maximum Demand (MD) in kW/kVA/power factor/phase and line voltages/currents etc (minimum 5 parameters) as per details given in the table below and enclosed annexure.

c) Daily Load Profile Parameters such as cumulative energy kWh (import/export)/cumulative kVAh (while kW- import/export)/cumulative energy kVArh (quadrant-1/2/3/4)/reactive energy high (V>103%)/low (V<97%), etc as per details given in the table below and enclosed annexure.

In addition to above the meter shall also record the Name plate details, programmable parameters (readable as profile), occurrence and restoration of tamper events along with the parameters (Table 30, 31 and 32 to 38 respectively of enclosed guideline document) Detail of category wise parameters requirement suitable for specific location such as feeder/DT metering, interface points/boundary points is given in following tables of guidelines document enclosed as annexure: Category Parameter group Annexure Table

No. Substation Feeder/ Distribution Transformer meter

Instantaneous parameters 22 Block Load Profile parameters

23

Boundary/Ring fencing/Interface Meters

Instantaneous parameters 24 Block Load Profile parameters

25

Daily Load Profile parameters

26

HT Consumer Meters Instantaneous parameters 27 Block Load Profile parameters

28

Billing Profile parameters 29 Substation Feeder/ Distribution Transformer/Boundary/Ring fencing/Interface/HT Consumer Meters

Name Plate details 30 Programmable Parameters 31 Event Conditions 32 to 38

Logging parameters for each of the event condition – shall be selected

Capture parameters for event as applicable (Event Log Profile)

39

14.0 DEMAND INTEGRATION PERIOD The maximum demand integration period may be set at 15 minute or 30 minute by purchaser as per requirement.

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15.0 MD RESET

It should be possible to reset MD by the following options: a) Communication driven reset b) Local push button c) Auto reset at 24:00 hrs at the end of each billing cycle

16.0 MARKING OF METERS

The marking of meters shall be in accordance with IS: 14697 /1999 (reaffirmed 2004). The meters shall bear marking “Purchased under R-APDRP scheme/property of DHBVN/UHBVN”.

The meter shall also store name plate details as given in the table 30 of annexure. These shall be readable as a profile as and when required.

17.0 COMMUNICATION CAPABILITY

The meter shall be provided with two ports for communication of the measured/collected data as per guideline document enclosed in the annexure, i.e. a hardware port compatible with RS 232 or RS 485 specifications which shall be used for remote access through suitable Modem (GPRS/GSM/EDGE/CDMA/PSTN/LPR) and an Optical port complying with hardware specifications detailed in IEC-62056-21. This shall be used for local data downloading through a DLMS compliant HHU. One-meter long cable, of suitable size, having facility at one end, for connecting to the optical port, other end shall be provided with RS – 232 Connector shall be provided, as spare cable, so that the optical port can be brought out the meter box. The meter shall have necessary facilities to transfer the data via the communication port, the hand held data collection device (DCD) and also to down load this on a P.C to get complete details in numeric form. The necessary software for this purpose shall be provided by the supplier, without any condition, free of cost

The RS 485 port shall be used at Substations suitable for multi-drop connections of the meter for exporting data to sub-station data logger/DCU/Computer and the remote end server. The RS 232 port shall be used at boundary points meters and Distribution Transformer meters capable to transfer and export data to the remote end server through suitable communication mediums (GPRS/GSM/EDGE/CDMA/ PSTN/LPR). Both ports shall support the default and minimum baud rate of 9600 bps.

18.0 HAND HELD UNIT (HHU)

To enable local reading of meters data a DLMS compliant HHU shall be used. The HHU shall be as per specification given in the enclosed guidelines document. It shall be compatible to the DLMS compliant energy meters that are to be procured/ supplied on the basis of this specification.

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19.0 TAMPER & FRAUD MONITORING FEATURES

The meter shall work satisfactorily under presence of various influencing conditions like External Magnetic Field, Electromagnetic Field, Radio Frequency Interference, harmonic Distortion, Voltage/Frequency Fluctuations, and electromagnetic High Frequency Fields etc. The meter shall be immune to abnormal voltage/frequency generating devices and shall record the occurrence and restoration of such tamper events along with parameters such as current, voltages, kWh, power factor, event code, date & time etc. (listed in Table 32 to 38 in enclosed document).

Tamper details shall be stored in internal memory for retrieval by authorized personnel through either of the following: i) HHU. ii) Remote access through suitable communication network.

Minimum 200 numbers of events (occurrences & restoration with date & time) should be available in the meter memory.

20.0 TYPE TESTS

The meter offered should have successfully passed all type tests described in the IS 14697 and the meter Data Transfer and Communication capability as per enclosed guidelines document. Type test certificate shall be submitted along with the offer and the same shall not be more than 36 months old at the time of bid submission. Make & type of major components used in the type-tested meter shall be indicated in the QAP. The condition are to be relaxed by the purchasers (utilities) for the bids to be issued in next six months (i.e. upto Feb 2010) to accommodate design, development and testing of the new standard meters, conforming to the guidelines document enclosed as annexure, by manufacturers. The bidder shall have to submit the required type test certificate (as per bid requirement) to the purchaser (utility) at the time of meters delivery.

Further Purchaser shall reserve the right to pick up energy meters at random from the lots offered and get the meter tested at third party lab i.e. CPRI / agencies listed at Appendix-C of Latest – standardization of AC static electrical energy meters – CBIP publication NO.-304/ NPL / CQAL/ ERTL / ERDA at the sole discretion of the Purchaser. The supplier has no right to contest the test results of the third party lab or for additional test and has to replace/take corrective action at the cost of the supplier.

It shall be the responsibility of the supplier to arrange such tests and Purchaser shall be informed of the date and time of conduction of tests well in advance to enable him to witness such tests. Test charges of the testing authority, for such successful repeat type tests, shall be reimbursed at actual by the Purchaser.

21.0 ACCEPTANCE & ROUTINE TESTS

Criteria for selection for such tests and performance requirements shall be as per IS 14697-1999 (reaffirmed 2004)

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Additional acceptance shall include Surge withstand (SWC) for 6 kVp

as per IEC 6205211, Lightning impulse test and HF disturbance test as per IS 14697. One sample meter per order from one of the offered lot shall be subjected to these specific tests. Meters subjected to these tests shall not be used after tests.

Accuracy tests shall be performed at the beginning and at the end of the acceptance tests specified.

22.0 QUALITY ASSURANCE: The manufacturer shall have a comprehensive quality assurance program at all stages of manufacture for ensuring products giving reliable, trouble free performance. Details of the bidder’s quality assurance and test set up shall be furnished with the bid. A detailed quality assurance program shall be finalized with the successful bidder during the award stage. Bidder shall furnish following information along with his bid: i) Organization structure of the manufacturer and his main sub-suppliers (PCBs, SMT

cards, CT/PT) with details of ‘QA’ setup, overall workflow; ii) Copy of system manual showing ‘QAP’ (Quality Assurance Plan) as actually practiced

during manufacturing and final testing. iii) List of raw materials and critical components (ASIC chip, crystal clock, memory register

Chip, transformers, optical ports etc.) with their suppliers; iv) Stage inspection of product before final testing; v) Procedure adopted for ‘In-situ’ testing of PCBs, after placement of surface mounted

component, for quantitative parametric variation of tolerance by self or sub-contractor. vi) Testing and calibration facility, date of calibration of test bench, manpower data of bench

operators; vii) Sample copies of test certificate of bought out components. viii) The manufacturer shall be responsible to pay penalty of Rs 20,000/- for each

occasion at which the fake inspection call has been made or the material is rejected during testing/inspection by the authorized agency/representative of the Nigam. This penalty would be in addition to the expenses incurred by the Nigam in deputing the Inspecting Officer, carrying out such inspection.

23.0 QUALIFYING REQUIREMENTS (as per annexure-A of NIT documents)

i) Bidder should be a manufacturer; ii) He should have all the facility in his works for design, assembly, quality assurance, burn-

in test (Fully assembled Energy Meter), testing (all routine and acceptance tests), automatic calibration of Energy Meter on software based test bench, qualified team of technical and software engineers;

iii) The average annual turnover of the manufacturer for Energy meters for the three (3) best financial years out of last five (5) years, should be at least Rs.** …………… Lakhs. (** is 2 x Package Cost x 12/ Work completion schedule in Months)

iv) Notwithstanding anything stated herein under, the Purchaser reserves the right to assess the capacity and capability of the bidder to execute the work, should the circumstances warrant such assessment in the overall interest of the Purchaser.

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24.0 GUARANTEE

The meter shall have a designed life of at least 10 years and the supplier shall be responsible to replace, free of cost, with no transportation or insurance - cost to the Nigam, up to destination, the whole or any part of the material which, under normal and proper use, proves defective in quality or workmanship, subject to the condition that the defect is noticed within 66 months from the date of receipt of material by the consignee or 60 months from the date of installation, which ever period may expire earlier. The consignee or any other officer of the Nigam, actually using the material, will give prompt notice of each such defect to the supplier as well as the Purchasing authority and the Controller of Stores. The replacement shall be affected by the supplier within a reasonable time, but not, in any case, exceeding 45 days. The supplier shall also arrange to remove the defective supply within reasonable period but not exceeding 45 days from the date of issue of the notice in respect thereof. The warranty for 60/66 months shall be one time. Upon the firm failing to do so, the damages / defects may be got rectified by the Nigam and the cost adjusted from the firm’s pending dues and/or security deposit against this or any other contract in force and the balance left be got deposited by the supplier. The Nigam may withhold the amount, equal to cost of defective material. The purchaser shall recover an equivalent amount plus 15% supervision charges, if the defective material is not repaired / replaced with in the above specified period. The cumulative damage rate during warrantee period should not exceed:- i) Up to one year 3% ii) Up to two years 4% iii) Up to three years 5% iv) More than four years 6% If the supplier fails to adhere to the above requirement, the Nigam may take any penal action against the supplier upto and including blacklisting.

25.0 FIXING & CONNECTION ARRANGEMENT Manufacturer shall ensure following technical points:

i) Meter shall be suitable for mounting on Simplex type vertical panel with front door; CAT-M4 disconnecting type TBs to be used for Current circuit; Panel wiring to be properly dressed and harnessed; External cables to enter panel from bottom gland plate using double compression glands.

ii) Energy Meter terminals block shall be adequately sized with regard to maximum conductor dimension, commensurate with current rating of Energy Meter.

26.0 CHALLENGE CLAUSE: The material offered/received after the inspection by the authorized Inspecting Officer may again be subjected to the test for losses or any other parameters from any testing house/in house technique of the Nigam having requisite capabilities and facilities. The results if found deviating/ unacceptable or non-complying to approved GTPs the lot

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shall be rejected and bidder shall arrange to supply the replacement within thirty (30) days of such detection at his cost including to & fro transportation. In addition to this penalty @10% of cost of the inspected lot of material shall be imposed.

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ANNEXURE - A

GUARANTEED TECHNICAL PARTICULARS FOR CT / PT OPERATED TRIVECTOR METERS /LT CT meter

1) Maker’s Name

2) Meter Make & Type

3) Fixing Arrangement

4) Basic current (Amperes)

5) Rated Maximum Continuous Current (Amperes)

6) Standard Reference Voltage & Frequency

7) Class of accuracy

8) Power Loss in each

i) Voltage circuit

ii) Current circuit

9) Minimum Starting Current

10) Type of display

11) No. of Digits

12) Type of output Device

13) Clearances and creepage distance in the

I. Terminal Block

II. Terminal cover

14) Material of

I. Terminal Block

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II. Terminal cover

15) Material of Terminals

16) Material of Meter Frame/Cover

17) Window arrangement & material

18) Number of seals provided

I. Main Meter Cover

II. Meter Terminal Cover

19) Total weight of the Meter

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ANNEX A

(Foreword)

INTRODUCTION TO STANDARDIZED METER PARAMETERS LIST

A-1 CLASSIFICATION OF PARAMETERS

The Metering Parameters have been identified and classified as follows:

a) Instantaneous Parameters b) Block Profile / Load Survey Parameters. c) Daily Profile Parameters. d) Parameters for accounting / billing. e) General Purpose quantities

i. Name Plate Details. ii. Programmable parameters

f) Event Conditions. The measurement and computation of each of these parameters and events shall be based on standard methods or based on utilities prudent practices or as directed by respective Regulatory Commission.

For each of the identified parameter, the OBIS code, Interface Class and the Attributes are given in the various tables in corresponding Annexure. The OBIS codes listed are applicable for LN referencing and is mandatory to adhere to by the SERVERS and CLIENTS.

A-2 INSTANTANEOUS PARAMETERS

The Instantaneous parameters shall be continuously updated by the meter hardware / software as per internal sampling and computation time. The energy values in the table shall be cumulative readings from the date of manufacturing or installation of meter as the case may be. These shall be continuously updated and last updated value shall be available for downloading as and when required. Each of the parameters shall be readable at any instant by the HOST from remote or by HHU at site. The snap shot of all the instantaneous values of all parameters shall be readable by the HOST computer.

A-3 PROFILE GENERIC OR LOAD SURVEY PARAMETERS (CAPTURE TIME BLOCK 15 OR 30 MINUTES)

This is an array of parameters identified for capturing and storing at specified time intervals or capture times. The capture times shall be either 15 or 30 minutes. The capture times

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shall be programmable by the utilities. The tables lists the parameters whose profile (survey) is to be captured and stored in the meter as per set capture time period. The profiles shall be readable at any time by the HOST from remote or by HHU (MRI) at site for any specified range and time.

In the case of Category B meters the capture time shall be of 15 minutes duration.

The data stored in the array shall be the average value for the captured time block and stored at the end of that block, except for energy values. The energy entries are the consumption during respective capture time block and posted at the end of that block. The array of data shall be retained inside the meter memory for the last 22 days for a capture period of 15 minutes or for the last 45 days for a capture period of 30 minutes. It is assumed that the number of load survey parameters is 5 which can be selected from the respective tables by the utilities. The storage days can be expanded by choosing less number of parameters.

The block load profiles shall not store or return values (typically zero values) for conditions where the meter is powered down for a full day, where a full day is defined as the 24 hour period from midnight 00 Hrs to the next midnight 00 Hrs. Under such conditions the block load profile for the entire 24 Hour period shall not be stored nor padded with zero entries. However if the meter is powered up even for a small amount of time (sufficient for it to boot up and record the Power up event) during the 24 Hour period, it shall store and return the Block load profile for the entire 24 hour duration.

A-4 PARAMETERS FOR ACCOUNTING / BILLING PURPOSE

These are parameters identified for accounting / billing purposes. These shall be generated by the meter for each billing cycle and stored in the memory. The set of data for last 6 (six) cycles shall be stored in the memory. At the end of each cycle corresponding set of data shall be readable by the HOST from remote or by HHU at site.

A-5 GENERAL PURPOSE QUANTITIES

A-5.1 Name Plate Details

These parameters are electrical and non-electrical quantities and are static in nature, grouped as “Name Plate Details”, containing pertinent information about the supplied meter. The parameters identified and grouped as “Name Plate Details” under this classification are applicable for all categories of meters( see Annex F).

A-.2 Programmable Parameters

These parameters are non electrical quantities. The parameters identified and grouped as “Programmable Parameters” shall be programmable by the Utility engineers. For the

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purpose of setting / altering the values of these parameters, the security and access rights in line with the methodology described in protocol, shall be mutually agreed between utility and manufacturer. The parameters shall be programmable by HOST from remote and HHU at site. These are applicable for all categories of meters( see Annex F).

A-6 EVENT CONDITIONS

A-6.1 Any abnormal or a tamper condition is defined as an Event. The meters shall identify and log both occurrence and restoration of such events. The meters shall also capture some of the parameters at the instance of above said log. This specification has identified the events to be logged and the parameters to be captured for each of those events( see Annex G).

A-6.2 This Companion Specification has further classified those events in sub groups for easy handling. The sub groups are

a. Voltage related events b. Current related events c. Power Failure related events d. Transactional events e. Other events f. Non rollover events g. Control events

A-6.3 The number of events stored in each compartment shall be decided by agreement between the Utility and Manufacturers. However the total number of events shall be 200.

A-6.4 The event conditions identified are listed in Table 37 to Table 43 of Annex G covering all the subgroups. For each type of event condition the parameters to be captured are listed in Table 44 of Annex G. The required capture parameters for selected event condition shall be chosen by the utility as per its practices and directives.

A-6.5 The types of events to be recorded may be selected by the Utility out of the list provided in tables Table 37 to Table 43 of Annex G as per Utility need and practice. The parameters for which Snapshot is to be recorded at time of tamper / event can also be selected out of list of parameters provided in “Capture Parameters” in Table 44 of Annex G.

A-6.6 The servers shall be capable of providing the entire list of parameters listed in the respective Annexure. However the utility as per its practices and directives may choose required parameters from the full list. Sequence of parameters in buffer shall be derived from capture object. The OBIS code for such selected parameters however shall remain as assigned.

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ANNEX B

(Clause 1.3)

INTRODUCTION TO METERING PARAMETERS WITH DATA IDENTIFIERS

B-1 Three categories of electricity meters have been selected for compiling comprehensive lists of metering parameters with their data identifiers as required for data networks in India for COSEM procedures and services. The relevant reference documents are listed in 2.

B-2 The meters complying with this specification shall be considered as servers in a data network. The data collecting devices at the head end or HHU shall function as client and seek required services from these servers. Table 21 lists the server categories with metering nomenclatures and Annex references.

Table 21 Categories of Meters (Clause B-2)

Sl No Server

Category Metering Nomenclature /

Purpose Annex

(1) (2) (3) (4)

i) A Energy Accounting and Audit Metering

C, F,G

ii) B Boundary / Bank / Ring / ABT Metering

D, F,G

iii) C HV (PT / CT) and LV (CT) consumer Metering

E, F,G

B-1.1 Category A Meter

This meter is identified for use at sub-station feeders and Distribution Transformer Centers. The parameters listed for this category is for “Energy Accounting and Audit” purposes (see also Annex C).

B-1.2 Category B Meter

This meter is identified for use at Meter Banks and Network boundaries. The parameters listed for this category is for import / export of energy. This meter is also suitable for Availability Based Tariff (ABT) regime (see also Annex D).

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.B-1.3 Category C Meter

This meter is identified for use at HV (PT and CT operated) and LV (CT operated) consumers. The parameters listed for this category is for consumers who draw energy from the grid. For consumers who also supply energy to grid, the category B Meter is recommended (see also Annex E).

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ANNEX C

(Clause B-1.1, Table 21)

PARAMETER LIST FOR ‘CATEGORY A’ METERS C-1 The parameters listed here are for Energy Accounting & Audit purposes. These meters are identified for Feeder metering and DTC metering where the power flow is unidirectional. In circumstances where bidirectional power flow is to be measured then Category B Meters shall be deployed.

C-2 The parameters identified are grouped under Instantaneous (Table 22) and Block load profile (Table 23). The tables include the name of the parameter, the OBIS code and Interface class.

C-3 Association Access Rights are as follows:

a) Public Client - Read Only for Clock and no access for other objects.

b) Meter Reader – Read Only for all objects.

c) Utility Setting – Read & Write for Clock and Read Only for others.

C-4 INSTANTANEOUS PARAMETERS

Each of the parameters is a separate entity. The OBIS code for each parameter is identified as per DLMS /COSEM protocol.

C-4.1 Snap Shot Of Instantaneous Parameters

The parameters of Table 22 shall be captured as a profile generic using the country specific OBIS code 1.0.94.91.0.255; the attribute 2 of each of the capture objects shall be copied into the profile at the instant of a request from the Host.

Table 22 Instantaneous Parameters for Class A Meters

(Clause C-2 & C-4.1)

Sl No Parameter OBIS Code

A.B.C.D.E.F

Interface Class No

(1) (2) (3) (4)

i) Real Time Clock – Date and Time 0.0.1.0.0.255 8

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ii) Current - IR 1.0.31.7.0.255 3

iii) Current – IY 1.0.51.7.0.255 3

iv) Current – IB 1.0.71.7.0.255 3

v) Voltage – VRN 1.0.32.7.0.255 3

vi) Voltage – VYN 1.0.52.7.0.255 3

vii) Voltage – VBN 1.0.72.7.0.255 3

viii) Voltage – VRY 1.0.32.7.0.255 3

ix) Voltage – VBY 1.0.52.7.0.255 3

x) Signed Power Factor –R phase 1.0.33.7.0.255 3

xi) Signed Power Factor - Y phase 1.0.53.7.0.255 3

xii) Signed Power Factor - B phase 1.0.73.7.0.255 3

xiii) Three Phase Power Factor – PF 1.0.13.7.0.255 3

xiv) Frequency 1.0.14.7.0.255 3

xv) Apparent Power – KVA 1.0.9.7.0.255 3

xvi) Signed Active Power – kW (+ Forward; - Reverse)

1.0.1.7.0.255 3

xvii) Signed Reactive Power – kvar (+ Lag; - Lead)

1.0.3.7.0.255 3

xviii) Cumulative Energy – kWh 1.0.1.8.0.255 3

xix) Cumulative Energy – kvarh – Lag 1.0.5.8.0.255 3

xx) Cumulative Energy – kvarh – Lead 1.0.8.8.0.255 3

xxi) Cumulative Energy – kVAh 1.0.9.8.0.255 3

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xxii) Number of Power-Failures. 0.0.96.7.0.255 1

xxiii) Cumulative Power-Failure Duration 0.0.94.91.8.255

3

xxiv) Cumulative Tamper Count 0.0.94.91.0.255

1

xxv) Cumulative Billing Count 0.0.0.1.0.255 1

xxvi) Cumulative Programming Count 0.0.96.2.0.255 1

xxvii) Billing Date 0.0.0.1.2.255 3

xxviii) Maximum Demand – kW 1.0.1.6.0.255 4

xxix) Maximum Demand – kVA 1.0.9.6.0.255 4

NOTES

1) The items at Sl No v), vi), and vii) are for 3Ф / 4W system of measurement with NEUTRAL as reference point.

2) The items at Sl No viii) and ix) are for 3 Ф / 3W system of measurement with Y-PHASE as reference point.

3) Signed Power factor: (+) indicates lag and (-) indicates lead.

4) The parameters at Sl No xviii) to xxvi) hold cumulative values at that instant from the date of manufacturing or installation of meter as the case may be.

5) The above list is identified for the purpose of communication to HOST or HHU.

6) The utilities may choose, based on needs, additional parameters for display purpose ONLY.

7) Item number at Sl No xxv) refers to the Billing Period Counter.

C-4.2 Scaler Profile

This profile is meant for capturing the Scaler-unit of each of the parameter listed in Table 22. This is modeled as profile generic (IC=7) and is assigned the country specific OBIS

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code 1.0.94.91.3.255. The capture objects for this profile shall include the scaler-unit attributes of the Instantaneous parameters listed above. Instantaneous parameters that do not have a scaler-unit (like IC 1) shall not be included in the capture objects list. The profile buffer shall have only one entry. This profile is not required to be updated periodically

C-5 BLOCK LOAD PROFILE PARAMETERS

This is an array of load survey data captured as a profile generic. The OBIS code is 1.0.99.1.0.255, with Interface class as 7. The capture objects of this block load profile are as per Table 23 and the captured attribute shall be attribute 2 of each interface class. The capture object values will be copied into buffer of this array automatically as per capture period which shall be set through OBIS code 1.0.0.8.4.255 of recording interval 1.

Association Access Rights are as follows:

a) Public Client - No access for all objects.

b) Meter Reader – Read only for all objects.

c) Utility Setting – Read only for all objects.

Table 23 Block Load Survey Parameters for Class A Meters

(Clause C-2 & C-5)


A.B.C.D.E.F

Interface Class No / Attribute

(1) (2) (3) (4)

i) Real Time Clock – Date and Time

0.0.1.0.0.255 8 / 2

ii) Current - IR 1.0.31.27.0.255 3 / 2

iii) Current – IY 1.0.51.27.0.255 3 / 2

iv) Current – IB 1.0.71.27.0.255 3 / 2

v) Voltage – VRN 1.0.32.27.0.255 3 / 2

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vi) Voltage – VYN 1.0.52.27.0.255 3 / 2

vii) Voltage – VBN 1.0.72.27.0.255 3 / 2

viii) Voltage – VRY 1.0.32.27.0.255 3 / 2

ix) Voltage – VBY 1.0.52.27.0.255 3 / 2

x) Block Energy – kWh 1.0.1.29.0.255 3 / 2

xi) Block Energy – kvarh – lag 1.0.5.29.0.255 3 / 2

xii) Block Energy – kvarh – lead 1.0.8.29.0.255 3 / 2

xiii) Block Energy – kVAh 1.0.9.29.0.255 3 / 2

NOTES

1) The items at Sl No v), vi), and vii) are for 3Ф / 4W system of measurement with NEUTRAL as reference point.


3) The parameters at Sl No ii) to ix) are the average values during the block period time and stored at the end of that time block.

4) The parameters at Sl No x) to xiii) are the actual energy consumption during that time block.

5) Capture objects for 3 Ф / 4W are items Sl No i) to vii) and x) to xiii)

6) Capture objects for 3 Ф / 3W are items Sl No i) to iv) and viii) to xiii)

7) Support for Selective access shall be as defined in 11.3

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C-6 PARAMETERS FOR ACCOUNTING / BILLING

The list of parameters in Table 22 and Table 23 shall be used for computing the daily accounting data at the HOST.

C-6.1 Scaler Profile

This profile is meant for capturing the Scaler-unit of each of the parameter listed in Table 23. This is modeled as profile generic (IC=7) and is assigned the country specific OBIS code 1.0.94.91.4.255. The capture objects for this profile shall include the scaler-unit attributes of the parameters listed above. The profile buffer shall have only one entry. This profile is not required to be updated periodically

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ANNEX D

(Clause B-1.2, Table 21)

PARAMETER LIST FOR ‘CATEGORY B’ METERS

D-1 The parameters listed here are for Boundary / Bank / Ring Fencing / ABT Metering. The meter records parameters under import and or export conditions.

D-2 The parameters identified for this are grouped under Instantaneous (Table 24), Block load profile (Table 25) and Daily Load profile (Table 26). The tables include the name of the parameter, the OBIS code and Interface class.

D-3 INSTANTANEOUS PARAMETERS



a) Public Client - Read Only for Clock and no access for other objects.



D-3.1 Snap Shot of Instantaneous Parameters

The parameters of Table 24 shall be captured as a profile generic using the country specific OBIS code 1.0.94.91.0.255. The attribute 2 of each of the capture objects shall be copied into the profile at the instant of a request from the Host.

Table 24 Instantaneous Parameters for Class B Meters

(Clause D-2 & D-3.1)


A.B.C.D.E.F

Interface Class No

(1) (2) (3) (4)


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ii) Current - IR 1.0.31.7.0.255 3

iii) Current – IY 1.0.51.7.0.255 3

iv) Current – IB 1.0.71.7.0.255 3

v) Voltage – VRN 1.0.32.7.0.255 3

vi) Voltage – VYN 1.0.52.7.0.255 3

vii) Voltage – VBN 1.0.72.7.0.255 3

viii) Voltage – VRY 1.0.32.7.0.255 3

ix) Voltage – VBY 1.0.52.7.0.255 3

x) Signed Power Factor - R phase 1.0.33.7.0.255 3




xiv) Frequency 1.0.14.7.0.255 3


xvi) Signed Active Power – kW (+ import: - export)

1.0.1.7.0.255 3


1.0.3.7.0.255 3

xviii) Cumulative Energy – kWh (Import) 1.0.1.8.0.255 3

xix) Cumulative Energy – kWh (Export) 1.0.2.8.0.255 3

xx) Cumulative Energy – kVAh(Import) 1.0.9.8.0.255 3

xxi) Cumulative Energy – kVAh(Export) 1.0.10.8.0.255 3

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xxii) Number of Power-Failures. 0.0.96.7.0.255 1

xxiii) Cumulative Power-Failure Duration 0.0.94.91.8.255

3

xxiv) Cumulative Tamper Count 0.0.94.91.0.255

1

xxv) Cumulative Billing Count 0.0.0.1.0.255 1

xxvi) Cumulative programming Count 0.0.96.2.0.255 1

xxvii) Billing Date 0.0.0.1.2.255 3

NOTES

1) The items at Sl No v), vi) and vii) are for 3Ф / 4W system of measurement with NEUTRAL as reference point.

2) The items at Sl No viii), ix) are for 3 Ф / 3W system of measurement with Y-PHASE as reference point.

3) Signed Power factor: (+) indicates lag and (-) indicates lead. 4) The parameters at Sl No xviii) to xxvi) hold cumulative values at that instant

from the date of manufacturing or installation of meter as the case may be. 5) The above list is identified for the purpose of communication to HOST or HHU. 6) The utilities may choose, based on needs, additional parameters for display

purpose ONLY. 7) Item number at Sl No xxv) refers to the Billing Period Counter

D-3.2 Scaler Profile

This profile is meant for capturing the Scaler-unit of each of the parameter listed in Table 24. This is modeled as profile generic (IC=7) and is assigned the country specific OBIS code 1.0.94.91.3.255. The capture objects for this profile shall include the scaler-unit attributes of the Instantaneous parameters listed above. Instantaneous parameters that do not have a scaler-unit (like IC 1) shall not be included in the capture objects list. The profile buffer shall have only one entry. This profile is not required to be updated periodically.

D-4 BLOCK LOAD PROFILE PARAMETERS

This is an array of load survey data captured as a profile generic. The OBIS code is 1.0.99.1.0.255, with Interface class as 7. The capture objects of this block load profile are

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as per Table 25 and the captured object shall be attribute 2 of each interface class. The capture object values will be copied into a buffer of this array automatically as per capture period which shall be set through OBIS code 1.0.0.8.4.255 of recording interval 1.


a) Public Client – No access for all objects



Table 25 Block Load Survey Parameters for Class B Meters

(Clause D-2 & D-4)


A.B.C.D.E.F


(1) (2) (3) (4)


0.0.1.0.0.255 8 / 2

ii) Frequency 1.0.14.27.0.255

3 / 2

iii) Voltage – VRN 1.0.32.27.0.255

3 / 2

iv) Voltage – VYN 1.0.52.27.0.255

3 / 2

v) Voltage – VBN 1.0.72.27.0.255

3 / 2

vi) Energy – Active Import 1.0.1.29.0.255 3 / 2

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vii) Energy – Net Active Energy 1.0.16.29.0.255

3 / 2

viii) Energy – Active Export 1.0.2.29.0.255 3 / 2

ix) Energy – kvarh – Quadrant I 1.0.5.29.0.255 3 / 2

x) Energy – kvarh – Quadrant II 1.0.6.29.0.255 3 / 2

xi) Energy – kvarh – Quadrant III 1.0.7.29.0.255 3 / 2

xii) Energy – kvarh – Quadrant IV 1.0.8.29.0.255 3 / 2

NOTES

1) The parameters listed in this table are for load survey purpose and are logged as per the block period time.

2) The Block period time for Interface meters is fixed at 15 min for which the data storage will be for 22 days.

3) The parameters at Sl No iii) to vi) are the average values of 15 min block and stored at the end of that time block.

4) The parameters at Sl No vii) to xii) are the actual energy consumption during the 15 min time block.

5) Item at Sl No ii) is an ABT parameter for absolute average value. 6) Item at Sl No vii) is an ABT parameter for Net energy in the current

15 min block. 7) Support for Selective access shall be as defined in Section 11.3.


This profile is meant for capturing the Scaler-unit of each of the parameter listed in Table 25. This is modeled as profile generic (IC=7) and is assigned the country specific OBIS code 1.0.94.91.4.255. The capture objects for this profile shall include the scaler-unit attributes of the parameters listed above. The profile buffer shall have only one entry. This profile is not required to be updated periodically.

D-5 DAILY LOAD PROFILE PARAMETERS

This is an array of load survey data captured as a profile generic at the end of 24 hours. The OBIS code is 1.0.99.2.0.255, with Interface class as 7. The capture objects of this daily load profile are as per Table 26 and the captured attribute shall be attributing 2 of each

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interface class. The capture object values will be copied into a buffer of this array automatically as per capture period which shall be set through OBIS code 1.0.0.8.5.255 of recording interval 2. The capture period attribute shall be statically fixed as 24 hours.


a) Public Client – No access for all objects



Table 26 Daily Load Profile Parameters for Class B Meters

(Clause D-2 & D-5)


A.B.C.D.E.F


(1) (2) (3) (4)

i) Real Time Clock – Date and Time 0.0.1.0.0.255 8 / 2

ii) Cumulative Energy – kWh – Import 1.0.1.8.0.255 3 / 2

iii) Cumulative Energy – kWh – Export 1.0.2.8.0.255 3 / 2

iv) Cumulative Energy – kVAh while kW Import

1.0.9.8.0.255 3 / 2

v) Cumulative Energy – kVAh while kW Export

1.0.10.8.0.255 3 / 2

vi) Reactive Energy High (V > 103%) 1.0.94.91.1.255

3 / 2

vii) Reactive Energy Low (V < 97%) 1.0.94.91.2.255

3 / 2

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viii) Cumulative Energy – kvarh – Quadrant 1

1.0.5.8.0.255 3 / 2

ix) Cumulative Energy – kvarh – Quadrant 2

1.0.6.8.0.255 3 / 2

x) Cumulative Energy – kvarh – Quadrant 3

1.0.7.8.0.255 3 / 2

xi) Cumulative Energy – kvarh – Quadrant 4

1.0.8.8.0.255 3 / 2

NOTES

1) The parameters listed in this table are meant for billing purpose and shall be logged at midnight (00 Hrs).

2) The storage time for these parameters is 22 days. 3) The parameters at Sl No ii) to xi) are cumulative values at that

instant from the date of manufacturing or installation of meter as the case may be.

4) Item at Sl No vi) is an ABT parameter. 5) Item at Sl No vii) is an ABT parameter. 6) Support for Selective access shall be as defined in Section 11.3



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ANNEX E

( Clause B-1.3, Table 21)

PARAMETER LIST FOR ‘CATEGORY C’ METERS E-1 The parameters listed here are for HT (PT / CT) and LT (CT) consumer metering. This meter records energy in import mode. These meters shall be capable of recording Import of energy. For customers who import energy and also export energy, use of category B meters is recommended.

E-2 The parameters identified for this are grouped under Instantaneous (Table27), Block load profile (Table 28), and Billing (Table 29). The tables include the name of the parameter, the OBIS code and Interface class.

E-3 INSTANTANEOUS PARAMETERS



a) Public Client - Read only for Clock and no access for other objects.



E-3.1 Snap Shot of Instantaneous Parameters

The parameters of Table 27 shall be captured as a profile generic using the country specific OBIS code 1.0.94.91.0.255. The attribute 2 of each of the capture objects shall be copied into the profile at the instant of a request from the Host.

Table 27 Instantaneous Parameters for Class C Meters

(Clause E-2 & E-3.1)


A.B.C.D.E.F

Interface Class No

(1) (2) (3) (4)

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ii) Current - IR 1.0.31.7.0.255 3

iii) Current – IY 1.0.51.7.0.255 3

iv) Current – IB 1.0.71.7.0.255 3

v) Voltage – VRN 1.0.32.7.0.255 3

vi) Voltage – VYN 1.0.52.7.0.255 3

vii) Voltage – VBN 1.0.72.7.0.255 3

viii) Voltage – VRY 1.0.32.7.0.255 3

ix) Voltage – VBY 1.0.52.7.0.255 3

x) Signed Power Factor –R phase 1.0.33.7.0.255 3




xiv) Frequency 1.0.14.7.0.255 3


xvi) Signed Active Power – kW (+ Forward;

- Reverse)

1.0.1.7.0.255 3


1.0.3.7.0.255 3

xviii) Number of Power-Failures 0.0.96.7.0.255 1

xix) Cumulative Power-Failure Duration 0.0.94.91.8.255 3

xx) Cumulative Tamper Count 0.0.94.91.0.255 1

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xxi) Cumulative Billing Count 0.0.0.1.0.255 1

xxii) Cumulative Programming Count 0.0.96.2.0.255 1

xxiii) Billing Date 0.0.0.1.2.255 3

xxiv) Cumulative Energy kWh

1.0.1.8.0.255 3 / 2

xxv) Cumulative Energy kvarh Lag

1.0.5.8.0.255 3 / 2

xxvi) Cumulative Energy kvarh Lead 1.0.8.8.0.255 3 / 2

xxvii) Cumulative Energy kVAh 1.0.9.8.0.255 3 / 2

NOTES

1) The items at Sl No v), vi) and vii) are for 3Ф / 4W system of measurement with NEUTRAL as reference point.


3) Signed Power factor – (+ indicates lag) and (- indicates lead). 4) The parameters at Sl No xviii) to xxii) hold cumulative values at that instant from

the date of manufacturing or installation of meter as the case may be. 5) The above list is identified for the purpose of communication to HOST or HHU. 6) The utilities may choose, based on needs, additional parameters for display

purpose ONLY. 7) Item at Sl No xxi) refers to the Billing Period Counter 8) Item at Sl No xxiii) - Data type to be same as for attribute 2 of IC 8, Clock.

E-3.2 Scaler Profile

This profile is meant for capturing the Scaler-unit of each of the parameter listed in Table 27. This is modeled as profile generic (IC=7) and is assigned the country specific OBIS code 1.0.94.91.3.255. The capture objects for this profile shall include the scaler-unit attributes of the Instantaneous parameters listed above. Instantaneous parameters that do not have a scaler-unit (like IC 1) shall not be included in the capture objects list. The profile buffer shall have only one entry. This profile is not required to be updated periodically.

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E-4 BLOCK LOAD PROFILE PARAMETERS

This is an array of load survey data captured as a profile generic. The OBIS code is 1.0.99.1.0.255, with Interface class as 7. The capture objects of this block load profile are as per Table 28 and the captured attribute shall be 2 of each interface class. The capture object values will be copied into a buffer of this array automatically as per capture period which shall be set through OBIS code 1.0.0.8.4.255 of recording interval 1.


a) Public Client – No access for all objects.



Table 28 Block Load Survey Parameters for Class C Meters

(Clause E-2 & E-4)


A.B.C.D.E.F


(1) (2) (3) (4)

i) Real Time Clock – Date and Time 0.0.1.0.0.255 8 / 2

ii) Current - IR 1.0.31.27.0.255 3 / 2

iii) Current – IY 1.0.51.27.0.255 3 / 2

iv) Current – IB 1.0.71.27.0.255 3 / 2

v) Voltage – VRN 1.0.32.27.0.255 3 / 2

vi) Voltage – VYN 1.0.52.27.0.255 3 / 2

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vii) Voltage – VBN 1.0.72.27.0.255 3 / 2

viii) Voltage – VRY 1.0.32.27.0.255 3 / 2

ix) Voltage – VBY 1.0.52.27.0.255 3 / 2

x) Block Energy – kWh 1.0.1.29.0.255 3 / 2

xi) Block Energy – kvarh – lag 1.0.5.29.0.255 3 / 2

xii) Block Energy – kvarh – lead 1.0.8.29.0.255 3 / 2

xiii) Block Energy – kVAh 1.0.9.29.0.255 3 / 2

NOTES

1) The parameters listed in this table are for load survey purpose and are logged as per the block period time.

2) The parameters at Sl No ii) to ix) are the average values during the block period time and stored at the end of that time block.

3) The parameters at Sl No x) to xiii) are the actual energy consumption during that time block.

4) Capture objects for 3 Ф / 4W are items at Sl No i) to vii) and x) to xiii) 5) Capture objects for 3 Ф / 3W are items at Sl No i) to iv) and viii) to xiii) 6) Support for Selective access shall be as defined in Section 11.3



E-5 BILLING PROFILE PARAMETERS

The contents of this table are for billing purpose.


a) Public Client – No access for all objects.

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Table 29 Billing Profile Parameters for Class C Meters

S.No Parameter OBIS Code

A.B.C.D.E.F


(1) (2) (3) (4)

i) Billing Date 0.0.0.1.2.255 3 / 2

ii) System Power Factor for Billing Period 1.0.13.0.0.255 3 / 2

iii) Cumulative Energy – kWh 1.0.1.8.0.255 3 / 2

iv) Cumulative Energy – kWh – TZ1 1.0.1.8.1.255 3 / 2

v) Cumulative Energy – kWh – TZ2 1.0.1.8.2.255 3 / 2

vi) Cumulative Energy – kWh – TZ3 1.0.1.8.3.255 3 / 2

vii) Cumulative Energy – kWh – TZ4 1.0.1.8.4.255 3 / 2

viii) Cumulative Energy – kWh – TZ5 1.0.1.8.5.255 3 / 2

ix) Cumulative Energy – kWh – TZ6 1.0.1.8.6.255 3 / 2

x) Cumulative Energy – kWh – TZ7 1.0.1.8.7.255 3 / 2

xi) Cumulative Energy – kWh – TZ8 1.0.1.8.8.255 3 / 2

xii) Cumulative Energy – kvarh – Lag 1.0.5.8.0.255 3 / 2

xiii) Cumulative Energy – kvarh – Lead 1.0.8.8.0.255 3 / 2

xiv) Cumulative Energy – kVAh 1.0.9.8.0.255 3 / 2

xv) Cumulative Energy – kVAh – TZ1 1.0.9.8.1.255 3 / 2

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xvi) Cumulative Energy – kVAh – TZ2 1.0.9.8.2.255 3 / 2

xvii) Cumulative Energy – kVAh – TZ3 1.0.9.8.3.255 3 / 2

xviii) Cumulative Energy – kVAh – TZ4 1.0.9.8.4.255 3 / 2

xix) Cumulative Energy – kVAh – TZ5 1.0.9.8.5.255 3 / 2

xx) Cumulative Energy – kVAh – TZ6 1.0.9.8.6.255 3 / 2

xxi) Cumulative Energy – kVAh – TZ7 1.0.9.8.7.255 3 / 2

xxii) Cumulative Energy – kVAh – TZ8 1.0.9.8.8.255 3 / 2

xxiii) MD – kW 1.0.1.6.0.255 4 / 2 ,5

xxiv) MD – kW – TZ1 1.0.1.6.1.255 4 / 2 ,5

xxv) MD – kW – TZ2 1.0.1.6.2.255 4 / 2 ,5

xxvi) MD – kW – TZ3 1.0.1.6.3.255 4 / 2 ,5

xxvii) MD – kW – TZ4 1.0.1.6.4.255 4 / 2 ,5

xxviii) MD – kW – TZ5 1.0.1.6.5.255 4 / 2 ,5

xxix) MD – kW – TZ6 1.0.1.6.6.255 4 / 2 ,5

xxx) MD – kW – TZ7 1.0.1.6.7.255 4 / 2 ,5

xxxi) MD – kW – TZ8 1.0.1.6.8.255 4 / 2 ,5

xxxii) MD – kVA 1.0.9.6.0.255 4 / 2 ,5

xxxiii) MD – kVA – TZ1 1.0.9.6.1.255 4 / 2 ,5

xxxiv) MD – kVA – TZ2 1.0.9.6.2.255 4 / 2 ,5

xxxv) MD – kVA – TZ3 1.0.9.6.3.255 4 / 2 ,5

xxxvi) MD – kVA – TZ4 1.0.9.6.4.255 4 / 2 ,5

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xxxvii) MD – kVA – TZ5 1.0.9.6.5.255 4 / 2 ,5

xxxviii) MD – kVA – TZ6 1.0.9.6.6.255 4 / 2 ,5

xxxix) MD – kVA – TZ7 1.0.9.6.7.255 4 / 2 ,5

xl) MD – kVA – TZ8 1.0.9.6.8.255 4 / 2 ,5

NOTES

1) The data are stored up to 6 billing cycles. The Billing profile is modeled as Profile generic (IC: = 7) object with OBIS Code 1.0.98.1.0.255. The capture objects of this load profile are as per Table-29. The capture object values will be copied into buffer of this object either automatically or asynchronously. The capture period is set to zero, billing action is controlled by billing dates as provided in 10 and table 31.

2) Support for Selective access shall be as defined in Section 11.3 3) The current cycle billing parameters shall be readable as the values of the latest

billing period, on demand. This shall be in addition to the last 6 billing period data which shall be available in the Profile buffer as the last 6 entries in the buffer.

4) The captured attributes in case of Interface Class 4 (Extended register) used for MD values will be attributes 2 and 5 (Value and Timestamp)



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ANNEX F

(Clause A-5)

GENERAL PURPOSE PARAMETERS

F-1 NAME PLATE DETAILS

The contents of Table 30 are common to all meters. The data are meter specific information.

Association Access Rights for Name Plate Details are as follows:

a) Public Client – No access for all objects except Meter Serial number.



Table 30 Name Plate Details Parameters

(Clause F-1)


A.B.C.D.E.F

Interface Class

(1) (2) (3) (4)

i) Meter Serial Number 0.0.96.1.0.255 1 (Data)

ii) Manufacturer name 0.0.96.1.1.255 1

iii) Firmware Version for meter 1.0.0.2.0.255 1

iv) Meter type (3P-3W / 3P-4W) 0.0.94.91.9.25 1

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5

v) Internal CT ratio 1.0.0.4.2.255 1

vi) Internal PT ratio 1.0.0.4.3.255 1

vii) Meter year of manufacture 0.0.96.1.4.255 1

NOTE For item Sl No iv), a value of “0” indicates 3P-3W; a value of “1”

indicates 3P-4W

F-2 Programmable Parameters.

Association Access Rights for programmable parameters as given in Table 31 are as follows:

a) Public Client – No Access for all objects except Real Time Clock.


c) Utility Setting – Read, Write for all objects.

Table 31 Programmable Parameters

(Clause F-2)


A.B.C.D.E.F

Interface Class

(1) (2) (3) (4)


0.0.1.0.0.255 8 (Clock)

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ii) Demand Integration Period 1.0.0.8.0.255 1 (Data)

iii) Profile Capture Period 1.0.0.8.4.255 1

iv) Single-action Schedule for Billing Dates

0.0.15.0.0.255 22

v) Activity Calendar for Time Zones etc.

0.0.13.0.0.255 20

NOTES

1) The parameters are programmable by the utility engineers with required access rights.

2) Unit for Demand Integration Period and profile capture period is in “seconds”.

3) Programming of any of the parameters shall increment the “Cumulative programming count” value.

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ANNEX G

(Clause A-6)

EVENT REFERENCE TABLE

G-1 EVENTS Any exceptional / fraud / tamper condition is considered as an Event and stored in an Event code object (OBIS: = 0.0.96.11.e.255 IC: = 1, values of E range from 0 to 6). The value attribute (attr-2) of this object stores identifier corresponding to most recent event occurred in the meter. Unique identifier is assigned to occurrence and restoration of all possible events (identified so far) in the event reference tables (Table 32 to 38). Thus event code object will tell only about the most recent event and to get a picture of all events and associated information (at the time of event) an Event log object is used. An event log object is modeled as Profile generic (OBIS: = 0.0.99.98.e.255 IC: = 7, values of E range from 0 to 6). The buffer attribute (attr-2) of this profile object will store (asynchronously) a new entry for every event (occurrence and restoration are considered as separate events). The capture objects for the event log object is define below in Table-39.

G-1.1 Indian Event Reference Tables The contents of Table 32 to 38 are common to all categories of meter for which the parameters are selected as per the category of meter.

Table 32 Indian Event Reference Table – Voltage Related

(Clause G-1 & G-1.1)

Sl No Event ID Descriptions

(1) (2) (3)

i) 1 R-Phase – PT link Missing (Missing Potential) – Occurrence

ii) 2 R-Phase – PT link Missing (Missing Potential) – Restoration

iii) 3 Y-Phase – PT link Missing (Missing Potential) – Occurrence

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iv) 4 Y-Phase – PT link Missing (Missing Potential) – Restoration

v) 5 B-Phase – PT link Missing (Missing Potential) – Occurrence

vi) 6 B-Phase – PT link Missing (Missing Potential) – Restoration

vii) 7 Over Voltage in any Phase - Occurrence

viii) 8 Over Voltage in any Phase - Restoration

ix) 9 Low Voltage in any Phase - Occurrence

x) 10 Low Voltage in any Phase - Restoration

xi) 11 Voltage Unbalance - Occurrence

xii) 12 Voltage Unbalance - Restoration

Table 33 Indian Event Reference Table – Current Related



(1) (2) (3)

i) 51 Phase – R CT reverse – Occurrence

ii) 52 Phase – R CT reverse – Restoration

iii) 53 Phase – Y CT reverse – Occurrence

iv) 54 Phase – Y CT reverse – Restoration

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v) 55 Phase – B CT reverse – Occurrence

vi) 56 Phase – B CT reverse – Restoration

vii) 57 Phase – R CT Open - Occurrence

viii) 58 Phase – R CT Open - Restoration

ix) 59 Phase – Y CT Open - Occurrence

x) 60 Phase – Y CT Open - Restoration

xi) 61 Phase – B CT Open - Occurrence

xii) 62 Phase – B CT Open - Restoration

xiii) 63 Current Unbalance - Occurrence

xiv) 64 Current Unbalance - Restoration

xv) 65 CT Bypass – Occurrence

xvi) 66 CT Bypass – Restoration

xvii) 67 Over Current in any Phase – Occurrence

xviii) 68 Over Current in any Phase – Restoration

Table 34 Indian Event Reference Table – Power Related



(1) (2) (3)

i) 101 Power failure (3 phase) – Occurrence

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ii) 102 Power failure (3 phase) – Restoration

Table 35 Indian Event Reference Table – Transaction Related



(1) (2) (3)

i) 151 Real Time Clock – Date and Time

ii) 152 Demand Integration Period

iii) 153 Profile Capture Period

iv) 154 Single-action Schedule for Billing Dates

v) 155 Activity Calendar for Time Zones etc.

Table 36 Indian Event Reference Table – Others



(1) (2) (3)

i) 201 Influence of Permanent Magnet or AC/ DC Electromagnet - Occurrence

ii) 202 Influence of Permanent Magnet or AC/ DC Electromagnet - Restoration

iii) 203 Neutral Disturbance - HF & DC - Occurrence

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iv) 204 Neutral Disturbance - HF & DC - Restoration

v) 205 Very Low PF - Occurrence

vi) 206 Very Low PF - Restoration

Table 37 Indian Event Reference Table – Non Roll Over Events


Sl.No. Event ID Descriptions

(1) (2) (3)

i) 251 Meter Cover Opening – Occurrence

Table 38 Indian Event Reference Table – Control Events

(Clause G-1.1)


(1) (2) (3)

i) 301 Meter disconnected

ii) 302 Meter connected

G-1.2 Capture Parameters For Event As Applicable (Event Log Profile)


a) Public Client - No access

b) Meter Reading - Read only

c) Utility Settings - Read only

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Table 39 Capture Parameters for Events

(Clause G-1)

Sl No Parameter A B C D E F IC

(1) (2) (3) (4) (5) (6) (7) (8) (9)

i) Date and Time of event 0 0 1 0 0 255 8 (Clock)

ii) Event Code 0 0 96 11 0 255 1 (Data)

iii) Current - IR 1 0 31 7 0 255 3 (Register)

iv) Current - IY 1 0 51 7 0 255 3 (Register)

v) Current – IB 1 0 71 7 0 255 3 (Register)

vi) Voltage - VRN (3 Ф / 4W)

1 0 32 7 0 255 3 (Register)

vii) Voltage – VYN (3 Ф / 4W)

1 0 52 7 0 255 3 (Register)

viii) Voltage – VBN (3 Ф / 4W)

1 0 72 7 0 255 3 (Register)

ix) Voltage - VRY (3 Ф / 3W)

1 0 32 7 0 255 3 (Register)

x) Voltage – VYB (3 Ф / 3W)

1 0 52 7 0 255 3 (Register)

xi) Power Factor – R phase 1 0 33 7 0 255 3 (Register)

xii) Power Factor – Y phase 1 0 53 7 0 255 3 (Register)

xiii) Power Factor – B phase 1 0 73 7 0 255 3 (Register)

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xiv) Cumulative Energy – kWh 1 0 1 8 0 255 3 (Register)

G-1.3 Note For Tables (32,33,34,35,36,37,38 and 39)

1) These are the event conditions generally recorded in consumer meters, utilities may select any the above event conditions based on their practice. The need and applicability of these events for other type of meters shall be considered by Utility.

2) Either Occurrence or Restoration is considered an event. 3) For each of the events a certain list of parameters will be captured. 4) The list capture parameters are given in Table 39. The utility shall select the

required parameters from the Table 39 as per their practice. 5) For each of the event captured “Cumulative tamper count” value will be

incremented except for events from Tables 34, 35, 37 and 38. 6) Capture parameters mentioned in Table 39 are captured when event

occurrence and restoration is logged. 7) For events in Table 34, 38 no parameters shall be captured along with the

event. 8) The attributes of each of the IC (Interface Class) is to be identified while

finalizing the Companion Standard. 9) For 3 Ф / 4W the reference point is NEUTRAL 10) For 3 Ф / 3W the reference point is Y-Phase 11) Support for Selective access shall be as defined in Section 11.3

G-2 Scaler Profile This profile is meant for capturing the Scaler-unit of each of the parameter listed in Table 39. This is modeled as profile generic (IC=7) and is assigned the country specific OBIS code 1.0.94.91.7.255. The capture objects for this profile shall include the scaler-unit attributes of the parameters listed above. Parameters listed above that do no have a scaler-unit attribute shall not be included in the capture objects of this profile. The profile buffer shall have only one entry. This profile is not required to be updated periodically.

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ANNEX H

(Clause 3.1.23 )

CONFORMANCE TESTING

H-1 Meters claiming conformance to this Companion Specification will be required to

a) Conform to the DLMS/COSEM base standards (IEC 62056.) as certified by the conformance test tool (CTT)

b) Conform to the specific requirements and constraints of this companion specification as certified by CPRI or any other laboratory having facilities for the purpose.

H-2 This certification shall ensure

a) All mandatory parameters applicable to the category of the meter under test are implemented

b) All data types where specified are conforming to this document

c) All Application Associations are implemented as specified in this document with all specified services supported

d) Association object lists conform to this document with access rights and OBIS codes as specified here

e) Event related DLMS objects are implemented with Event identifiers as specified in the Event reference tables in this document

H-2.1 The test report from an accredited laboratory and having membership with DLMS UA shall be considered as a proof of conformance of protocol implementation. H-2.2 Systems once created in accordance with this companion specification and contemporary standards, shall be deemed acceptable, provided such systems are tested and certified through standard evaluation process.

UTTAR HARYANA BIJLI VITRAN NIGAM

SPECIFICATION No. 10/P-19/DD-II/UHBVN

TECHNICAL SPECIFICATION FOR LT SINGLE CORE 31/2 CORE AND FOUR PVC INSULATED UNARMOURED CABLE OFF SIZES FOR WORKING VOLTAGE UPTO & INCLUDING 1100V, FOR SERVICE CONNECTION.

OFFICE OF THE CHIEF ENGINEER/PD&C UHBVN, PANCHKULA (HARYANA)

TECHNICAL SPECIFICATION FOR LT SINGLE CORE 31/2 CORE AND FOUR PVC INSULATED UNARMOURED CABLE OFF SIZES FOR WORKING VOLTAGE UPTO & INCLUDING 1100V, FOR SERVICE CONNECTION. 1. SCOPE: - This specification provides for design, manufacture inspection, at manufacture’s works, testing before dispatch, supply and delivery of unarmored single core 31/2 core and 4 core PVC sheathed Aluminum conductor cables for voltage upto 1.1 K.V. 2. STANDARD: - LT distribution unarmoured cables shall be suitable for service voltage up to 1100 Volts (640 volts to earth) and made from high conductivity Aluminum conductor insulated with PVC compound and having outer sheathing of PVC compound. The cables shall be strictly in conformity with ISS-1554/part-I/1988 with latest amendments/edition if any and shall be ISI/IEC marked the inner and outer sheathing shall be carried out as per relevant ISS. However, material manufactured as per any other international Standard which offers equivalent or material better in quality and workmanship as compared to mentioned standards shall also be acceptable. Aluminum conductor complying with IS: 8130-1984 shall be used. 3. CLIMATIC CONDITIONS:- The cable shall work satisfactorily under the following Climatic conditions:-

I) Maximum ambient temperature. 50o c ii) Minimum ambient temperature. -2.5o c iii) Maximum relative humidity 100% iv) Minimum relative humidity 26% v) Altitude Below 1000 maters

above mean sea level. vi) Average no. of Rainy days per annum. 120 vii) Average annual rain fall 900 mm viii) Maximum wind pressure 195 Kg/meters2

4. TECHNICAL PARTCULARS: - The cable shall be suitable for use on 50 Hz

three phase AC solidly earthed Natural power system working voltage of 3x240/415 volt. 4.1 SHEATHING:- a) 4 Core Cables: - The supplier has the option to provide inner and outer

sheathing of PVC Compound by single or separate pressure extrusion process as per relevant ISS.

b) 31/2 Core cables :-

i) Inner and outer sheathing shall be provided by separate operation process only.

ii) Where Inner and outer sheathing are to be provide with PVC (compound by separate operation) the sheathing are to be provided by pressure extrusion process.

iii) Where Inner and outer sheathing are to be provide with thermo plastic material or proofed tape which shall not be harder than PVC used for

insulation and outer sheathing shall be provided with pressure extrusion process.

Note: - Cables with sheathing by sleeves extrusion shall not be accepted.

5. SIZES:-The normal sizes of the cables shall be as per schedule of requirements as per NIT.

6. TESTS:-

6.1 TYPE TESTS:- A copy of Type Tests Reports for the tendered type and size of cable carried at Govt. /Recognized Test House should be submitted along with the tender. The type tests shall be carried out as per IS: 1554/part/1988,IS-8130:1984. These type tests should have been carried out not earlier than five years from the date of opening of Bids. Tenders not accompanied with copies of Type-Test certificates are liable turbo rejected. The following shall constitute Type Tests:-

Sr. No.

Tests For Required ref to:- For test Method Ref. to part No. of IS:10810

a) Test on Conductor: 1. Tensile test 2. Wrapping test 3. Conductor resistance

test.

IS:8130-1984 I S:8130-1984 IS:8130-1984

2 3 5

b) Test for thickness and insulation and sheath.

9,12,14 Table 2,4 and 7

6

c) Physically tests for insulation and sheath:

1) Tension strength and elongation at break.

2) Loss of mass in air oven.

3) Ageing in air oven 4) Shrinking test. 5) Heat shock test.

6) Hot deformation. 7) Thermal stability.

IS:5831-1984 IS:5831-1984 IS:5831-1984 IS:5831-1984 IS:5831-1984 IS:5831-1984 IS:5831-1984

7 10 11 12 14 15 See note.

d) Insulation resistance test. IS:5831-1984 43 e) High voltage test (water

imuncrsion test) 16.3 of IS:1554 45

f) Flammability test 16.2 of IS: 1554 45 g) Additional Ageing test 16.4 of IS: 1554 53

6.2 ROUTINE TEST:- The following shall constitute routine tests:-

a) Conductor resistance test. b) High voltage test at room temperature.

All Routine Tests shall be carried out at manufacturer’s works by the

supplier. Copies of routine test certificates shall be submitted along with the inspection report for approval. 6.3 ACCEPTANCE TEST:- The following shall constitute the acceptance tests

which shall be got carried out by the inspecting officer during inspection: a) Tensile test. b) Wrapping test. c) Conductor Resistance test and nominal X-sectional area of conductor &

neutral. d) Tests for thickness of insulation and sheath. e) Tensile strength and elongation at break of insulation and sheath. f) Insulation resistance test. g) High voltage test. h) Flammability test.

Inspection officer shall carry out following type test also during inspection at firm’s works on all the lots offered for inspection.

a) Shrinking test b) Hot deformation test. c) Thermal stability test.

6.4 Ageing test: - The ageing test shall be carried out from any recognized/

Govt. Test house on the first lot offered for inspection on every size of cable sample drawn by the inspection officer as per relevant ISS with latest amendments.

7. MANUFACTURER IDENTIFICATION: - ‘PROPERTY OF UHBVN’ along with brand name, manufacture name, voltage rating, size, and year of manufacture in English shall be embossed on the outer sheath of the cable at regular intervals of approximately 1 to 1.5 meter. 8. INSPECTION AND TEST: - An authorized representative of the Nigam shall inspect, examine and test the equipment/material in respect of quality, size and ratings as per ISS/IEC mentioned above at the manufacturers works during or after the manufacture of goods prior to dispatch on receipt of a clear notice of minimum two weeks in advance to be reckoned from the date of receipt of the same by the purchaser. No material will be allowed to be dispatched without prior inspection and approval. The inspecting officer of the purchaser may also inspect the material during the course of by manufacture. In case, inspection of any consignment is walved off by the purchaser, the supplier will be required to furnish the requisite test certificates (for acceptance as well as routine tests) for approval. It will be the responsibility of the supplier to make adequate arrangements for testing of material at their works without any additional charge

to the purchaser. All testing instruction and appliances will be made available and material destroyed/consumed during testing will be to the account of the supplier. The purchase reserves the right to carry out Type Test as per Indian standard specifications with latest version thereof. These tests will be carried out an independent & recognized test house/agency/laboratory. All expenses whatsoever for carrying out these tests shall be to the supplier’s account. The

purchaser has right to have the tests carried out at any Govt,/Recognized Test agency in case of dispute in quality, size and ratings as per relevant ISS.

8.1 SAMPLING OF CABLES:- a) Scale of sampling: - Samples shall be taken and tested from each lot for

ascertaining the conformity of the lot to the required specifications. b) The number of samples to be selected as per table given below at

random (the randomness of selection, random number tables shall be used as per IS: 4905-1968. No of drums to be taken permissible number of as sample(n)

Sr. No. of Drums/No. of Coils/Reels in lot.

No. of Drums to be taken as sample.

Permissible number of defectives

(n) (n) (n) Upto 50 3 0 51 to 100 5 0 101 to 300 13 0 301 to 500 20 1 501 to above. 31 2

The Inspector shall have the option to take the samples (s) from any point in the length of any drums selected at random for carrying out various tests and total length of that particular drum (s) of such two pieces because of this sampling in such a particular case will be considered as one length. 8.2 CHECK MEASUREMENT OF CABLE LENGTH: - The manufacturer will provide necessary arrangement for checking of length at his own cost by the inspecting officer as per sampling plan. Out of the total quantity of drums offered for inspection, in no case less than two drums shall be selected for verification of length. If any of the drums is found short in length than the length specified, the whole of the lot shall be rejected. 9. QUALITY ASSURANCE PLAN: - The tenderers must supply an attested photocopy of valid ISI License/other International certification mark if any along with the tender, failing which their tenders are liable to be rejected. List of manufacturing facilities available shall be submitted the tender. List of testing facilities available for final testing of the cables shall be submitted with the tender. 10. Packing: -The cable shall be packed and supplied in non-returnable wooden drums provided with cast iron bushings to resist any damage during transit. Material offered for inspection should be duly packed and provided with blank lead seals for the purpose of scaling by the inspecting officer. The supplier will put their own seals also on the two ends of the cables. 11. DRUM LENGTH: - The cables shall be supplied in standard lengths as under:-

Cables upto 185 Sq, mm = 500 Meters =5% Cables above 185 Sq.mm = 250 Meters=5% Non standard length not less than 100 meters each shall be acceptable upto 5% of the ordered quantity. A tolerance of =5% is permissible allotted to each consignee with overall =2% tolerance on the ordered quantity for completion of order. 12. MARKING: - The marking on the drums shall have the following information’s:-

a) Trade mark, if any. b) Name of the manufacturer. c) Nominal cross sectional area of conductor of the cable. d) Year of manufacture. e) Type of cable and voltage for which it is suitable. f) Length of Cable on the drum/reel. g) Approximate gross weight. h) Number of cores and colour of crores. i) Net weight of the cable. j) Drum/reel identification no. k) Purchase Order No. and Date. l) Consignee’s name with designation. m) ISI mark/IEC mark. n) Direction of rotation of drum/reel (by means of an arrow). o) Reference IS: 1554/Part-1/1988

13. SCHEDULE OF GUARANTEED AND GUIDING TECHNICAL PARTICULARS:- The tenderers must supply the detailed guaranteed and other technical particulars as detailed in Appendix-I. For values, use of ‘Dash’ ‘Do’ ‘Blank; or as per ISS/IEC will not be entertained. Superintendent Engineer/P&D UHBVN, Panchkula

SCHEDULE OF TECHNICAL PARTICULARS FOR SINGLE CORE, 31/2 CORE AND 4 CORE LT PVC INSULATED ALUMUIUM CABLES. GUARANTEED TECHNICAL PARTICULARS a) Name of Manufacturer. b) Place of Manufacturer. c) Brand 2. Voltage grade. 3. Standard applicable 3.1 ISS/IEC marked or not. 3.2 Validity of ISS/IEC License (Enclosed

Completed upto date copy of license) 4. Type of Cable and conductor Material. 5. Nos./Nominal area of cores (No./size in sq.mm) 5.1 Nominal area of neutral (Sq.mm) 6. Shape of Conductor. 7. Nos. /Nominals dia of strand in conductor. (No. /dia in mm).

a) Main core(No./mm) b) Neutral core(No./mm)

8. Thickness of insulation a) Nominal (mm). b) Minimum (mm)

9 Minimum thickness of inner sheaths(mm) 10 Thickness of sheaths.

c) Nominal (mm). d) Minimum (mm)

11. Maximum resistance of conductor at 20oc (Ohm/Km.) 12. Minimum Volume resistivity at 27oc (Ohm/Km.). 13. Continuous current carrying capacity of cables.

a) In duct (Amp) b) In air (Amp) c) In ground (Amp)

B. GUIDING TECHNICAL PARTICULARS 1. Overall diameter finished cable with = tolerance (in mm). 2. Weight of the conductor with = tolerance per Km. (in Kgs.) 3. Weight of insulation with = tolerance per Km. (in Kgs.) 4. Weight of sheathing & filler with = tolerance per Km. (in Kgs.) 5. Total Weight of cable with = tolerance per Km. (in Kgs.) C. PROPERTIES OF PVC (INSULATION SHEATH)

1. Source of PVC compound. 2. Dielectric constant. 3. Dielectric strength Kg/mm. 4. Specific Gravity. 5. Tensile strength 6. Elongation at break. 7. Thermal Resistivity

(Name and Address of Supplier)

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