Request for Information
SCE’s Advanced Metering Infrastructure Program
December 2, 2005
Table of Contents
Background…………………………………………………………………..3
RFI Objectives……………………………………………………………….4
Vendor Engagement Approach………………………………………………4
RFI Responses………………………………………………………………..5
Contact Information…………………………………………………..5
Response Schedule……………………………………………………5
RFI Questions & Response…………………………………….…….6
Future Communications…………………………………………………….6
Proprietary Information……………………………………………………..6
Product Endorsements………………………………………………………6
Disclaimer……………………………………………………………………6
APPENDIX…………………………………………………………………8
B: Conceptual AMI System Functionality……………………………9
C: Specification E-100 SSM (Meter Requirements)………………….10
Background
SCE, the utility, is separate from the other Edison International (EIX) Companies, which are not regulated by the California Public Utilities Commission (“CPUC”). SCE is the largest subsidiary of Edison International and has over 110 years of experience in the transmission and distribution of electricity. SCE is California’s second largest investor-owned electric utility company supplying power to a population of over 11 million people, with over 4.3 million residential and business customers. Please visit the company web site at for more detailed information. On the company home page under the “About SCE” tab, visitors will also find a service area map depicting SCE’s service coverage area.
In 2004, the California Public Utilities Commission (CPUC) required that SCE and the other California Investor Owned Utilities analyze and develop business cases surrounding “Advanced Metering Systems” capable of supporting dynamic tariffs, facilitating operational and other cost reductions, and ultimately reducing peak-energy demand through enhanced load control and demand response capabilities[1]. SCE evaluated the available commercial solutions at the time, performed the required analysis, and found that the “best” full meter deployment business case yielded a significantly negative net present value (NPV). SCE’s evaluation of the available commercial technology solutions identified the need for more cost justified integrated system features and capabilitiesthat could deliver significantly more operational, cost, and customer benefits.
As a result, SCE submitted an application to the CPUC on March 30, 2005 to pursue development of anext generation AMI technology that will meet SCE’sbusiness objectives and system requirements for SCE’s five million customers spread across its 50,000 square mile territory. SCE proposed a multi-phase approach, with Phase I and II over the next three years encompassing the development effort.System-wide deployment is anticipated in Phase III contingent upon success in Phases I and II. The goal of this technology development is to develop, acquire and deploy a durable, reliable, and extensible AMI solution. The following table outlines the key activities and duration for the various phases in SCE’s overall development and deployment effortspanning seven and one-half (7 ½ ) years.
The following table outlinesall phases of the technology and deployment effort.
Table 1
Phase / Duration / Key Activity1 / 18 months / Functional & Non-Functional Requirements Development
System Architecture
Cost/Benefit Analysis
Small Scale Technology Trials (e.g. integrated disconnect, Home Area Network)
Product Bench Testing (Controlled Lab Environment)
2 / 18 months / Business Process and Back-Office Systems Analysis
Conduct Field Trials – Limited Deployments of compliant technologies
Business Case –in-Chief Development
3a / 12 months / CPUC Approval Process
Pre-Deployment Activities
3b / 42 months / Full-scale system and meter deployment
RFI ObjectiveS
On December 1, 2005, the CPUC approved SCE’s application for Phase I scope and funding. In anticipation of approval, SCE began the process to define business requirements and AMI system architecture in November 2005. SCE engaged IBM, EnerNex and KEMA Consulting to work with internal technical and functional experts through a systems engineering approach. SCE also seeks to begin formally engaging potential AMI vendorsto identify a candidate pool of vendors that have developed or are well underway in the process of developing a commercial AMI solution that aligns with SCE’s business objectives, system requirements and development timeline.
As such, SCE intends to use this RFI as a first step in the next generation metering system procurement process. SCE plans to employ a staged development approach that will lead to identifying, testing and deploying next generation candidate technologies. SCE expects to work closely with candidate AMI solutions providers to further develop their next generation technology.
The following table outlines the Phase 1 technology procurement activities and timeline.
Table 2
Milestones / Time / ObjectiveRFI Part A / Q4 2005 / Identify qualified AMI technology vendors
Release
Functional Requirements / Q1 2006 / Publish SCE’s AMI business and functional requirements
RFI Part B / Q2 2006 / Identify candidate AMI technology solutions based on SCE’s functional & non-functional requirements for bench testing
RFP / Q1 2007 / Field testselection from bench tested AMI technology solutions
Vendor Engagement Approach
SCE envisions collaboration with candidate AMI solution providers throughout all phases of this program. The following table outlines key Phase I development activities.
Table 3
Key Activity / ObjectivesVendor Engagement & Capability Assessment / Work closely with candidate solution providers regarding their product development roadmaps and to confirm their capability in meeting SCE’s objectives. Includes collaboration and due diligence on product development
Pre-commercial
Technology Assessment / Vendor site visits as needed for witness testing and/or review of 3rd party testing to confirm pre-commercial technology works in a controlled environment and supports SCE requirements.
Commercial
Technology Testing / SCE anticipates that qualified solution providers will submit commercial product for SCE bench testing to verify performance and functionality.
SCE is attempting to gain a better understanding of those companies serious about providing a “next generation” AMI solution, to better understand where your company might be in the development process, and to better determine which companies SCE might work with as it moves forward with its development effort. SCE is also interested in obtaining more information about your company’s alignment with SCE’s vision (see “APPENDIX B” included in this solicitation) and the status of your company’s current and near term development efforts as they relate to this vision.
There will be many vendors and products involved with any comprehensive AMI solution. Broad categorization of these entities might include: 1) meter vendors, 2) AMI communication solution providers, 3) meter data management systems and 4) in-premise device vendors (e.g. smart communicating thermostats, wired or wireless in-home display devices, remotely activated load switches, etc.). The intended audience of this first RFI only includes those companies that will be engaged in the first two product categories (meter manufacturers and communication solution providers).
SCE is not currently evaluating meter data management systems, but anticipates beginning evaluations of these systems after the system architecture design is complete. SCE also anticipates engaging in-premise device manufacturers at a later date, primarily from the standpoint of understanding interface requirements, encouraging necessary product development, and working to ensure communications compatible device product availability.
If (1) your company is working on development of a next generation advanced metering system, (2) would classify your company as falling within the first two specified product categories, and (3) are interested in working with SCE on this development effort, please continue to read the terms of this request and then complete and return the Response Template included as an attachment and titled “APPENDIX A_SCE_AMI_RFI_Response Template”.
CONTACT INFORMATION
The following e-mail address has been developed and designated by SCE as the primary means of contact (the “SCE RFI Contact”) for the purposes of this RFI: All RFI related questions should be directed to this address.
RESPONSE SCHEDULE
The schedule for the RFI process is as follows, however, vendors are advised that this schedule is subject to change at SCE’s discretion:
Friday, December 2nd, 2005. RFI documents will be sent to selected vendors via e-mail.
Friday, December 16th, 2005. By 2:00 PM pacific standard time,vendors must provide three (3) hard copies (unbound and sent to the address below) and one (1) electronic copy (sent via e-mail to ) of their complete response package.
Hard Copies should be mailed to: Southern California Edison
2244 Walnut Grove Ave,
Rosemead, CA 91770
To the Attention of: Judee Apodaca, G.O.1, Quad 1A
Vendor responses to the RFI (including those delivered in person or by mail courier service) should be clearly marked on the outside of each package with "CONFIDENTIAL – REQUEST FOR INFORMATION AMI PROGRAM" and "RESPONSE DUE DATE: 12/16/05.”
RFI QUESTIONS
Vendors should submit via email any questions to the SCE RFI Contact. All questions will be responded to via email and all answers will be distributed to the entire RFI recipient list.
RFI RESPONSE FORMAT
SCE requests that vendor’s responses conform to the format provided in the attached AMI RFI Response Template documentwhichwas included with this solicitationand to specifically address the content of the requested information. The inclusion of general marketing materials or technical manuals is discouraged. SCE reserves the exclusive right to determine if a response is incomplete or non-responsive. SCE will distribute the responses to an internal review team for evaluation. SCEalso requests that response submissions adhere to the submission deadline as specified above.
FUTURE COMMUNICATIONS
As stated in Table 2, SCE intends to identify qualified AMI technology vendors through this RFI Part A process. As such, a refined list of AMI technology vendors will be identified to participate in RFI Part B, also identified in Table 2. It should be noted, however, that SCE understands the potential for changes in circumstances over the 42-month period appropriated for the 3 phases of the AMI Program. For vendors not selected to participate in RFI Part B, SCE will provide periodic opportunities to update information included in the Response Template of RFI Part A. Formal communications will be distributed at a future date to be determined.
PROPRIETARY INFORMATION
This RFI and the material contained herein is copyrighted by Southern California Edison Company. The information contained herein is SCE’s proprietary information and is not to be copied or otherwise distributed in any manner without the express written consent of SCE.
Vendor agrees that responses shall place no obligation on Edison, its subsidiaries or any of its employees, to maintain these responses in confidence or to otherwise take any steps to protect these responses. Further, vendor agrees that Edison may use and publicly disclose as required for regulatory purposes any responses submitted.
pRODUCT eNDORSEMENTS
Unless vendor has SCE’s prior written permission, it will not (1) associate vendor’s products or services with SCE or SCE’s operations or (2) represent to anyone that SCE has employed or endorsed vendor’s products or services. Breach of this section entitles SCE to immediately eliminate the vendor from any further consideration.
DISCLAIMER
This RFI shall not be construed in any manner to create an obligation on the part of SCE to enter into any contract, or serve as a basis for any claim whatsoever for reimbursement of costs for efforts expended. Furthermore, the scope of this RFI may be revised at the option of SCE at any time, or this RFI may be withdrawn or canceled by SCE at any time. SCE reserves the right to waive formalities and to add, modify, or delete items, requirements, and terms or conditions prior to the conclusion of this RFI whenever it is deemed to be in SCE’s best interest. Notwithstanding any other provision of this RFI, vendor is hereby specifically advised that this RFI is an informal solicitation of information only, and is not intended to be (nor is it to be construed as) engaging in formal competitive bidding pursuant to any statute, code, ordinance, rule, or regulation. Therefore, SCE shall not be obligated by any responses received by SCE or by any statements or representations, whether oral or written, that may be made by SCE, and SCE reserves the unqualified right to reject any or all responses submitted hereunder for any reason whatsoever. SCE shall be held free from any liability resulting from the use or implied use of the information submitted in any response to this RFI. Submission of a response shall constitute the vendor's acknowledgment of this notice and the vendor's acceptance of this disclaimer.
SCE reserves the right to verify all information provided by vendor via direct contact with the vendor's prior clients and prior personnel, and the vendor must agree to provide and release necessary authorizations, if required, for SCE to verify any of the vendor's previous work and the vendor’s qualifications to perform this work. Misstatements of experience, qualifications and scope of prior work may be grounds for disqualification of the vendor. SCE reserves the right to amend the schedule of RFI activities, as it deems necessary.
Appendix
Attachment B – Conceptual AMI System Functionality
Attachment C – Specification E-100 SSM (Meter Requirements)
APPENDIX B: CONCEPTUAL AMI SYSTEM FUNCTIONALITY
SCE conducted an extensive AMI solution technology search over the past year, and found that a more feature rich, durable and reliable solution would create a positive business case. This analysis was based on a conceptual feature set that might be integrated with next generation meters and remote communication devices. We found that expected end-point pricing decreased dramatically as compared with the increase in overall integrated features and system functionality. The following graphic provides a conceptual framework of capabilities.
APPENDIX C: SPECIFICATION E-100 SSM
Watthour Meters
Table of Contents
1.0 GENERAL REQUIREMENTS4
1.1 Terms and Definitions4
1.2 Applicability4
1.3 Compliance4
1.4 Verification4
1.5 Changes and Deviations4
1.6 Exceptions4
1.7 Responsibility4
1.8 Conflicts4
1.9 Inquiries4
2.0 SCOPE4
2.1 General4
2.2 Compliance with Standards4
2.3 Purchasing Contract5
2.4 Applicability5
2.5 Minimum Requirements5
2.6 Previous Approvals5
3.0 PERFORMANCE5
3.1 Longevity and Reliability5
3.2 Failure Definition5
4.0 QUALITY COMPLIANCE5
4.1 100% Testing5
4.2 Sample Testing6
4.3 Acceptable Quality Level (AQL)6
4.4 Sample Size6
4.5 Acceptance Criteria6
4.6 Single Phase Meters7
4.7 Three-Phase Meters7
4.8 Demand Run-up Test7
4.9 Accuracy Distribution (Bar-X)8
4.10 Defective Meters8
4.11 Shipment Rejection8
4.12 Inspection8
4.13 Visual Inspection9
4.14 Reporting9
5.0 PRODUCT CHANGES9
5.1 Notification9
6.0 FUNCTIONAL REQUIREMENTS10
6.1 Measured Quantities10
6.2 Additional Measured Quantities10
6.3 Forward and Reverse Measurements10
6.4 Loss Compensation Measurements10
6.5 Basic Default Metering Function10
6.6 Demand Metering Function10
6.7 Time-Of-Use (TOU) Metering Function11
6.8 Self-Read TOU Metering Function11
6.9 Load Profile Function11
6.10 Function During Power Disturbances12
6.11 Meter Test Mode Function12
6.12 Meter Clock13
7.0 DISPLAY REQUIREMENTS13
7.1 LCD Display13
7.2 Viewing Characteristics13
7.3 Display Components13
7.4 Digits13
7.5 Time Format14
7.6 Date Format14
7.7 Operating Modes14
7.8 Normal Mode14
7.9 Alternate Mode14
7.10 Display Items14
7.11 Constants14
8.0 METER DIAGNOSTICS14
8.1 Self Test14
8.2 Diagnostic Checks14
8.3 Pulse Overflow15
8.4 Error and Warning Displays15
8.5 Error Reset15
8.6 Metering Installation Diagnosis15
9.0 PROGRAMMING AND SOFTWARE15
9.1 Interface Requirement15
9.2 Meter Programmers15
9.3 Supplier Software15
10.0 COMMUNICATION16
10.1 Baud Rate16
10.2 Optical Port Location16
10.3 Optical Cable16
10.4 ANSI Protocols16
11.0 OPTIONAL METER FUNCTIONS16
11.1 Pulse Outputs16
11.2 Additional Contact Output16
12.0 ACCURACY16
12.1 ANSI C12.2016
12.2 Factory Calibration17
12.3 Test Equipment17
12.4 Creep17
12.5 Starting Current17
12.6 Start-Up Delay17
12.7 Pulse Outputs17
12.8 Disk Emulation17
13.0 ELECTRICAL REQUIREMENTS17
13.1 Meter Forms, Voltages and Classes17
13.2 Single-Phase and Three-Phase Meters17
13.3 Expanded Voltage18
13.4 Circuit Boards18
13.5 LCD Display Connectors18
13.6 Metering Application18
13.7 Connections18
13.8 Meter Register Power Supply18
13.9 Clock18
13.10 Batteries18
13.11 Battery Identifiers19
13.12 Battery Safety19
13.13 Electromagnetic Compatibility19
14.0 MECHANICAL REQUIREMENTS19
14.1 General19
14.2 Solar Radiation19
14.3 Corrosive Atmospheres19
14.4 Meter Package20
14.5 Cover Requirements20
14.6 Nameplate20
14.7 Demand Reset20
15.0 SECURITY21
15.1 Billing Period Reset21
15.2 Meter Password21
15.3 Test Mode21
15.4 Program Security21
15.5 Revenue Protection21
1.0GENERAL REQUIREMENTS
1.1Terms and Definitions
1.1.1Specification
This document consisting of 15 sections
1.1.2Meter
For the purposes of this specification, an electricity meter is referred to as “meter” or “meters.”
1.1.3 Bidder/Manufacturer/Supplier
These terms apply to meter providers and are synonymous as used in this specification
1.2Applicability
This Specification applies to any single and multi-stator electricity meter purchased by Edison for the purpose of collecting revenue information.
1.3Compliance
Meters obtained from this Specification shall comply with requirements identified herein.
1.4Verification
Edison reserves the right, at its sole discretion, to test meters to verify compliance with the Specification.
1.5Changes And Deviations
Edison reserves the right to make partial or complete changes to this Specification and to approve deviations from the Specification.
1.6Exceptions
Any product exceptions must be approved in writing by Edison.
1.7 Responsibility
Suppliers shall provide a complete functioning system and shall assume full responsibility for integrating all hardware, firmware and software they furnish, regardless of origin.
1.8Conflicts
If conflicts arise, requirements of the Specification will supersede all other requirements
1.9Inquiries
Inquires about the specification shall be addressed to:
Southern California Edison Company
Procurement Agent -Meters Procurement Division
14660 Chestnut Street, Westminster, CA 92683
2.0SCOPE
2.1General
The Specification provides the minimum functional and performance requirements for the meter. All requirements in the Specification are intended to assure expected life cycles, accuracy, reliability and minimum maintenance of the meter. It is not intended to inhibit design, construction and creativity of the Supplier. Some requirements, however, are specified to maintain the compatibility and interchangeability of the Meter.
2.2Compliance with Standards
Interms of safety, performance, and susceptibility to natural or induced phenomena, the meter's design, construction, and operation shall conform to requirements established in the following standards or the latest revision:
2.2.1ANSI C12.1 -1995, Code for Electricity metering
2.2.2ANSI C12.7 -1993, Requirements for Watthour meter Sockets
2.2.3ANSI C12.10 -1997, Code for Electromechanical Watt-hour meters
2.2.4ANSI C12.20 -1998, Code for Solid State Demand Registers
2.2.5ANSI MH10.8M -1983, Specification for Bar Code Symbols
2.2.6ANSI/ASTM-8117-73 (Z118.1-1974}, Method of Salt-fog Spray
2.2.7IEEE C37.90.1-2002, SWC Surge Testing
2.2.8IEC 61000-4-2- 2001, Electrostatic Discharge Requirements
2.2.9IEC 61000-4 -4- 2001, Electrical Fast Transient/Burst Requirements
2.3Purchasing Contract
The Specification will be used in conjunction with Edison’s procurement process and if not included in Edison's contract, it is implied by reference.
2.4Applicability
The Specification covers Edison’s current and near future requirements for electricity meters used in revenue applications. The Specification does not cover the requirements for substation or inter-tie metering. Meters that Edison purchases under this specification will have a limited number of specific features. Edison will identify the required features with each order.
2.5 Minimum Requirements
As a minimum each Meter supplied shall meet the minimum requirements of this specification and the requirements of “Direct Access Standard for Metering and Meter Data In California (March 1999), Meter Approval Testing.”
2.6 Previous Approvals
Meter designs specified and approved by Edison prior to January 1, 2001 remain approved.