Download Business Practice Manual for Direct Telemetry Version

Business Practice Manual for
Direct Telemetry
Version 345.0
Last Revised: 124/2803/2012201404/03/2014
CAISO Business Practice Manual
BPM for Direct Telemetry
Approval History
Approval Date
: April 14, 2014
Effective Date
: June 6, 2014
BPM Owner
: Benik Der-Gevorgian
BPM Owner’s Title
: Director, Market Services
Revision History
Version
Date
1
8/2/2011
2
12/14/2011
Description
Initial BPM submittal document
Added requirement for data quality flag propagation as new
Section 6.8, added requirement for preliminary revenue metering
package to Section 10.2, removed unnecessary definitions from
Section 4, and made changes to ISP circuit exceptions in Section
5.3 per BPM PRR 489. Effective Date 12/01/11
3
11/14/12
Removal of the Full Network Model time line guide and changes
to EIR less than 10MW.
4
3/21/14
Added clarifying language indicating that Reliability Demand
Response Resources (RDRR) are not required to provide
telemetry and therefore exempt from direct telemetry
requirements to section 2.1 (PRR 725)
54
4/03/14
Added language to section 6.10 exempting DRP’s from the RIG
aggregation location limitation in the provision of real time
telemetry data for Proxy Demand Resources (PDR) (PRR 726)
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TABLE OF CONTENTS
1. Telemetry BPM Introduction ............................................................................................... 7 1.1 Purpose of California ISO Business Practice Manuals................................................. 7 1.2 Purpose of this Business Practice Manual ................................................................... 8 1.3 References ................................................................................................................... 8 2. Overview of Telemetry to the CAISO ................................................................................. 9 2.1 Telemetry Process........................................................................................................ 9 2.2 Overview of Installation & Validation of Telemetry ..................................................... 10 2.3 Overview of Flow of Real-time Data ........................................................................... 11 2.4 Organization of the BPM ............................................................................................ 11 3. CAISO Responsibilities ..................................................................................................... 12 3.1 Overview of CAISO Responsibilities .......................................................................... 12 3.2 Telemetry Validation ................................................................................................... 12 3.2.1 Overview of Telemetry Installation Validation Process ................................... 13 3.2.2 CAISO Certification Responsibilities ............................................................... 14 4. Telemetry Standards Overview ........................................................................................ 16 5. Communications ................................................................................................................ 16 5.1 Overview..................................................................................................................... 16 5.2 Real-time Communications ........................................................................................ 16 5.3 ECN Communications Exception ............................................................................... 17 5.4 Communication Technical Principles.......................................................................... 17 5.5 Data Validation and Confidentiality............................................................................. 17 5.6 Protocols..................................................................................................................... 18 5.7 Voice Communications ............................................................................................... 18 5.8 Communications During Telemetry Failure ................................................................ 18 6. Operational Requirements ................................................................................................ 19 6.1 Unit Telemetry Visibility .............................................................................................. 19 6.2 Performance Monitoring ............................................................................................. 19 6.2.1 Direct Telemetry Timing Requirements .......................................................... 19 6.2.2 PDR Timing Requirements ............................................................................. 19 6.3 CAISO Real-time Communication Options ................................................................. 21 6.3.1 SSL TCP to Serial Data Option ...................................................................... 21 6.3.2 SSL TCP to TCP Clear Text Option ............................................................... 21 Page 2
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6.3.3 RIG Hardware Option ..................................................................................... 22 6.4 SSL\TCP to Serial or TCP Clear Text Option ............................................................. 25 6.5 RIG Hardware Option ................................................................................................. 26 6.6 CAISO’s EMS Interrogations: ..................................................................................... 27 6.7 RIG Responses DNP Object and Variation Types ..................................................... 27 6.8 Quality Flag Propagation to DNP ............................................................................... 28 6.9 Maximum MW RIG Limitation ..................................................................................... 28 6.10 RIG Location Requirements ....................................................................................... 29 6.11 RIG Resource Limitation ............................................................................................ 29 6.12 Cost Responsibility ..................................................................................................... 29 7. Telemetry Data Points List ................................................................................................ 30 7.1 Point Matrix................................................................................................................. 30 7.1.1 Analog and Digital Notes ................................................................................ 34 8. Availability & Maintenance................................................................................................ 35 8.1 CAISO Reliability Requirements................................................................................. 35 8.2 CAISO Controlled Grid Operation and Market Availability Requirement .................... 35 8.3 RIG Operation and Maintenance ................................................................................ 35 8.3.1 Software Configuration Management with No Impact to CAISO EMS ........... 37 8.3.2 Data Base Configuration and Management Impacting CAISO EMS .............. 38 8.3.3 Routine Testing/ Maintenance of RIGs ........................................................... 38 9. RIG Implementation ........................................................................................................... 40 9.1 Engineering / Deployment .......................................................................................... 40 9.2 RIG Database Development....................................................................................... 40 9.3 Telecommunication Circuit Installation and Power Requirements ............................. 40 9.4 Temporary Telemetry Exemptions ............................................................................. 40 10. FNM Database Process and RIG Installation .................................................................. 41 10.1 CAISO FNM Database Process ................................................................................. 41 10.2 New Database Submission ........................................................................................ 41 10.3 RIG Database Submittal Timeline .............................................................................. 41 10.4 ECN Physical Circuit Protection to the Resource ....................................................... 41 10.5 ECN Circuit Monitoring ............................................................................................... 41 10.6 ECN Agreement ......................................................................................................... 42 10.7 Standards For Point-to-Point Testing with the CAISO................................................ 43 Page 3
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10.8 Required Personnel for Point testing .......................................................................... 44 10.9 Upgrade or Replacement RIG .................................................................................... 44 10.10 SLIC Outage for Meter or RIG work ........................................................................... 44 10.11 RIG Certificates .......................................................................................................... 46 10.12 RIG Generation Acceptance Test............................................................................... 47 10.13 Final RIG Documentation ........................................................................................... 47 10.14 Wind and Solar FNM Documentation Required ......................................................... 48 11. AGC Operational Requirements for Generating Units ................................................... 49 11.1 Required DNP and Telemetry Data Points for AGC ................................................... 49 11.2 AGC Control (Bumpless Transfer).............................................................................. 49 12. Non-Spinning Reserve Logic and Testing....................................................................... 50 12.1 Non-Spinning Reserve Definition ............................................................................... 50 12.2 Non-Spinning Reserve Logic Requirements .............................................................. 50 12.3 Non-Spinning Reserve Testing................................................................................... 50 12.4 Proxy Demand Resource Non-Spinning Reserve Testing ......................................... 51 13. Eligible Intermittent Resources (EIR)............................................................................... 52 13.1 Applicability................................................................................................................. 52 13.2 Power Reliability Requirements.................................................................................. 52 13.3 Basic Meteorological Data .......................................................................................... 52 13.3.1 Meteorological Wind Speed ............................................................................ 52 13.3.2 Meteorological Wind Direction ........................................................................ 52 13.3.3 Meteorological Barometric Pressure............................................................... 53 13.3.4 Meteorological Ambient Temperature............................................................. 53 13.4 Wind Generation......................................................................................................... 53 13.4.1 Meteorological Station Requirements ............................................................. 53 13.4.2 Designated Turbines....................................................................................... 54 13.4.3 Topographical Map ......................................................................................... 54 13.5 Solar Generation ........................................................................................................ 54 13.5.1 Meteorological Station Requirements ............................................................. 54 13.5.2 Meteorological Data Requirements ................................................................ 55  Flat Plate Solar Photovoltaic ............................................................................... 55  Flat Panel Solar Collector .................................................................................... 55  Low Concentration Solar Photovoltaic................................................................. 55 Page 4
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 High Concentration Solar Photovoltaic ................................................................ 55  Concentrated Solar Thermal ............................................................................... 56  Heliostat Power ................................................................................................... 56  Greenhouse Power Tower .................................................................................. 56  Sterling Engine .................................................................................................... 56 13.6 Solar Meteorological Data Tables .............................................................................. 57 14. Proxy Demand Resource (PDR) ....................................................................................... 59 14.1 PDR Point Requirements ........................................................................................... 59 14.1.1 Real Load MW ................................................................................................ 59 14.1.2 PDR Unit Connectivity Status (PDR UCON) .................................................. 59 14.1.3 Bias Load ........................................................................................................ 59 14.1.4 PDR Unit Ready to Start and Start Status ...................................................... 59 14.1.5 Pseudo Generation MW ................................................................................. 59 14.1.6 Status` and Pseudo Generation flow .............................................................. 60 15. RIG Aggregator .................................................................................................................. 62 15.1 Applicability................................................................................................................. 62 15.2 RIG Aggregator Responsibility ................................................................................... 62 15.3 RIG Aggregator Authorization .................................................................................... 62 16. CAISO Security Policy ....................................................................................................... 63 16.1 Referencing CAISO Information Security Documents ................................................ 63 17. Real-time Point Definitions ............................................................................................... 64 17.1 ANALOG VALUES ..................................................................................................... 64 17.1.1 Unit Gross Megawatts (Gross MW) ................................................................ 64 17.1.2 Unit Net Megawatts (Net MW) ........................................................................ 64 17.1.3 Unit Point of delivery Megawatts (POD MW) .................................................. 65 17.1.4 Unit Auxiliary Load Megawatts (Aux MW) ...................................................... 65 17.1.5 Gross Reactive Power (Gross Megavar (MVAR)) .......................................... 65 17.1.6 Point of delivery Megavars (POD MVAR) ....................................................... 66 17.1.7 Net Reactive Power (Net MVAR).................................................................... 66 17.1.8 Auxiliary Load Reactive Power (Aux MVAR) .................................................. 67 17.1.9 Generating Unit Terminal Voltage (KV) .......................................................... 67 17.1.10 Unit Operating High Limit (UOHL) (AGC Units Only) .................................. 67 17.1.11 Unit Operating Lower Limit (UOLL) (AGC Units Only) ................................ 68 Page 5
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17.2 Digital Values.............................................................................................................. 69 17.2.1 Unit Generator Breaker................................................................................... 69 17.2.2 Unit Connectivity Status (UCON) .................................................................... 69 17.2.3 Unit Control Status (UCTL) ............................................................................. 69 17.2.4 CAISO Unit Authority Switch (UASW) ............................................................ 70 17.2.5 Unit Automatic Generation Control (UAGC) ................................................... 71 17.2.6 Automatic Voltage Regulator (AVR) and Power System Stabilizer (PSS)
71 Status
17.2.7 Peaking Unit Ready to Start and Start Status` ............................................... 72 17.3 Switchyard Values ...................................................................................................... 72 17.3.1 Switchyard Line and Transformer MW and MVAR Values ............................. 72 17.3.2 Switchyard Bus Voltage .................................................................................. 73 17.3.3 Switchyard Device Status ............................................................................... 73 17.3.4 Aggregated Units ............................................................................................ 73 17.3.5 Aggregated Gross MW and MVAR ................................................................. 73 17.3.6 Aggregated Net MW and MVAR ..................................................................... 74 17.3.7 Aggregated Aux MW and MVAR .................................................................... 74 17.3.8 Aggregated Point of delivery MW ................................................................... 74 17.3.9 Aggregated Point of delivery MVAR ............................................................... 74 17.3.10 Aggregated Unit Connectivity (UCON) ....................................................... 74 17.3.11 Aggregated Peaking Unit Start and Ready to Start .................................... 74 17.4 Wind and Solar Point Definitions ................................................................................ 74 17.4.1 Direct Irradiance (DIRD) ................................................................................. 74 17.4.2 Global Horizontal Irradiance (GHIRD) ............................................................ 74 17.4.3 Global Irradiance / Plane of Array Irradiance (PAIRD) ................................... 75 17.4.4 Diffused Irradiance.......................................................................................... 75 17.4.5 Back Panel Temperature (BPTEMP) .............................................................. 75 18. Drawing Requirements ...................................................................................................... 76 19. Sub-LAP Resource Names................................................................................................ 78 Page 6
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1.
BPM for Direct Telemetry
Telemetry BPM Introduction
Welcome to CAISO BPM for Direct Telemetry. In this Introduction you will find the following
information:
 The purpose of CAISO BPMs
 What you can expect from this CAISO BPM
 Other CAISO BPMs or documents that provide related or additional information
1.1
Purpose of California ISO Business Practice Manuals
The Business Practice Manuals (BPMs) developed by CAISO are intended to contain
implementation detail, consistent with and supported by the CAISO Tariff, including:
instructions, rules, procedures, examples, and guidelines for the administration, operation,
planning, and accounting requirements of CAISO and the markets. Exhibit 1-1 lists CAISO
BPMs.
Exhibit 1-1: CAISO BPMs
Title
BPM for BPM Change Management
BPM for Candidate CRR Holder Registration
BPM for Compliance Monitoring
BPM for Congestion Revenue Rights
BPM for Credit Management
BPM for Definitions & Acronyms
BPM for Direct Telemetry
BPM for Managing Full Network Model
BPM for Market Instruments
BPM for Market Operations
BPM for Metering
BPM for Outage Management
BPM for Reliability Requirements
BPM for Rules of Conduct Administration
BPM for Scheduling Coordinator Certification & Termination and
Convergence Bidding Entity Registration & Termination
BPM for Settlements & Billing
BPM for Transmission Planning Process
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1.2
BPM for Direct Telemetry
Purpose of this Business Practice Manual
The BPM for Direct Telemetry covers the responsibilities of the CAISO, Participating
Generators, Participating Loads, Proxy Demand Resources, and Scheduling Coordinators
representing these entities for telemetry installation, validation, and maintenance, in addition to
the telemetry data required.
The provisions of this BPM are intended to be consistent with the CAISO Tariff. If the provisions
of this BPM nevertheless conflict with the CAISO Tariff, the CAISO is bound to operate in
accordance with the CAISO Tariff. Any provision of the CAISO Tariff that may have been
summarized or repeated in this BPM is only to aid understanding. Even though every effort will
be made by CAISO to update the information contained in this BPM and to notify Market
Participants of changes, it is the responsibility of each Market Participant to ensure that he or
she is using the most recent version of this BPM and to comply with all applicable provisions of
the CAISO Tariff.
A reference in this BPM to the CAISO Tariff, a given agreement, or any other BPM or
instrument, is intended to refer to the CAISO Tariff, that agreement, or BPM or instrument as
modified, amended, supplemented, or restated.
The captions and headings in this BPM are intended solely to facilitate reference and not to
have any bearing on the meaning of any of the terms and conditions.
1.3
References
Other reference information related to this BPM includes:
 The BPM for Full Network Model
 The BPM for Metering
 The CAISO’s standard documents pertaining to direct telemetry, posted on the CAISO
Website at the following link: http://www.caiso.com/thegrid/operations/gcp/index.html
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2.
BPM for Direct Telemetry
Overview of Telemetry to the CAISO
Welcome to the Overview of Telemetry section of the BPM for Direct Telemetry. In this section
you will find the following information:
 A description of the telemetry process;
 A diagram of the telemetry installation and validation process; and
 A diagram of the flow of telemetry data
2.1
Telemetry Process
This BPM sets forth requirements for the provision of real-time data to the CAISO applicable to
all Participating Generators’ Generating Units providing Ancillary Services (including Regulation)
or Energy in the CAISO’s markets. While This this BPM also applies to Participating Loads and
Proxy Demand Resources participating in the CAISO’s markets it does not apply to Reliability
Demand Resources, which have no requirement to provide telemetry. This BPM describes the
process and procedures used by the CAISO to obtain real-time data from the resources of
Participating Generators, Participating Loads, Proxy Demand Resources, and Scheduling
Coordinators representing these entities for operating the CAISO Balancing Authority Area
reliably and balancing the CAISO Markets.
A Generator with a Generating Unit connected to the electric grid within the CAISO Balancing
Authority Area that (1) has a capacity of ten (10) megawatts (MW) or greater that is not exempt
pursuant to the CAISO Tariff, (2) provides Ancillary Services, or (3) is an Eligible Intermittent
Resource not exempt pursuant to the CAISO Tariff must install, in accordance with the
requirements specified in this BPM, equipment and/or software that can interface with the
CAISO’s Energy Management System (EMS) to supply telemetered real-time data. That
Remote Intelligence Gateway (RIG) or equivalent will serve as the primary means for secure
communications and direct control between the Generator’s Generating Unit and the CAISO’s
EMS as a prerequisite for participation in any of the CAISO markets requiring real-time data. In
some circumstances, the CAISO allows for aggregation of Generating Units and the associated
direct telemetry. While this BPM does not address all issues related to Aggregated Units, it
does address the required points for Aggregated Units herein. The resources of Participating
Loads and Proxy Demand Resources are also subject to these requirements for telemetry of
real-time data.
This BPM provides information regarding:
 The CAISO installation requirements for telemetry facilities;
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 How the CAISO validates direct telemetry facilities for Participating Generators,
Participating Loads, Proxy Demand Resources, and Scheduling Coordinators
representing these entities; and
 Direct telemetry validation, testing, and maintenance requirements for telemetry for
resource owners’ facilities participating in the CAISO markets.
2.2
Overview of Installation & Validation of Telemetry
Exhibit 2-1 illustrates the process for installation and validating telemetry installation for owners
of resources required to provide real-time telemetry.
Exhibit 2-1: Overview of Installation and Validation of Telemetry Installations
Design Telemetry
Database from
single line
diagrams
Resource Owner
Telemetry Design
CAISO
Agreement
(i.e. PGA)
RIG
Engineering
Resource Owner
and CAISO RIG
Engineering
finalized Database
Telemetry
Installation and
Integration
Database is submitted for the next
EMS\FNM built.
Establish Communication link between
The Resource Owner
And CAISO EMS
Validate Real-time
data with CAISO
EMS
Validate Resource
Owner Real-time
data to CAISO EMS
Declared
Commercial
Operations
Test energy phase
and real data
validation
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2.3
BPM for Direct Telemetry
Overview of Flow of Real-time Data
Exhibit 2-2 illustrates the flow of real-time telemetry data between resources and the CAISO’s
EMS and from the CAISO’s EMS to other CAISO systems.
Exhibit 2-2: Overview of Real-Time Telemetry Data Flow
Resource Owner
CAISO Interrogates
Telemetry Device
CAISO EMS
CAISO Pi
Historian
Generation Control
and Balancing
Real-time data
stored for
CAISO usage
only
2.4
Organization of the BPM
The following Sections describe the respective responsibilities of the CAISO, Participating
Generators, Participating Loads, Proxy Demand Resources, and Scheduling Coordinators
representing these entities for provision of direct telemetry. Sections 4 through 17 describe
provisions for configuration, installation, and validation of telemetry facilities for resources
providing Ancillary Services or Energy only, and for wind, solar, and Proxy Demand Resources.
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3.
BPM for Direct Telemetry
CAISO Responsibilities
Welcome to the CAISO Responsibilities section of the BPM for Direct Telemetry. In this section
you will find the following information:
 An overview of CAISO responsibilities
 A description of the installation and point to point validation process for telemetry
facilities
 A description of the documentation requirements
 A description of the testing and completion requirements
3.1
Overview of CAISO Responsibilities
CAISO Tariff Section 7.6.1(d) Actions For Maintaining Reliability Of CAISO Controlled Grid
Section 7.6.1(d) of the CAISO Tariff provides the CAISO authority to obtain the control over
Generating Units that it needs to control the CAISO Controlled Grid and maintain reliability by
ensuring that sufficient Energy and Ancillary Services are procured through the CAISO Markets.
That provision requires each Participating Generator to take, at the direction of the CAISO, such
actions affecting such Generator as the CAISO determines to be necessary to maintain the
reliability of the CAISO Controlled Grid. Such actions include (but are not limited to) the
provision of communications, telemetry and direct control requirements, including the
establishment of a direct communication link from the control room of the Generator to the
CAISO in a manner that ensures that the CAISO will have the ability to direct the operations of
the Generator as necessary to maintain the reliability of the CAISO Controlled Grid, except that
a Participating Generator will be exempt from these requirements with regard to any Generating
Unit with a rated capacity of less than ten (10) MW, unless that Generating Unit is certified by
the CAISO to provide Ancillary Services.
This BPM sets forth the provisions by which the CAISO implements the foregoing
responsibilities for direct telemetry.
3.2
Telemetry Validation
The CAISO has overall responsibility for validating real-time data to the CAISO. Some of this
responsibility is accomplished by the responsibilities placed on the resource owner (or
aggregator, in the case of some resources), which may include responsibilities satisfied by the
Scheduling Coordinator for the resource. This Section 3.2 summarizes the respective
certification responsibilities of the CAISO and the resource owner (or aggregator or Scheduling
Coordinator, as applicable).
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3.2.1 Overview of Telemetry Installation Validation Process
Exhibit 3-1 provides a high level illustration of the overall validation process for telemetry
facilities.
Exhibit 3-1: Telemetry Installation Validation Process
Prospective participant signs
applicable agreement
CAISO Contracts group submits project into RIMS
and review and approval process begins
CAISO reviews telemetry package and
identifies any engineering variances
RIG Engineering reviews required documentation
and sends out initial spreadsheet to resource
owner
Make changes
and resubmit to
RIG Eng.
Resource owner verifies that required real-time
points can be provided in real-time from plant
control system
CAISO RIG Engineering submits database
for the next FNM build
Resource owner procures and installs CAISO
approved telemetry equipment
Resource owner integrates telemetry equipment
Resource owner orders and installs
required communication circuit and
equipment for real-time data to the CAISO
EMS
and tests all required real-time points for the
CAISO EMS.
Testing and validating real-time data
to the CAISO EMS
Resources owner supplies all finish paper work
and informs CAISO project management that all
testing is complete
CAISO RIG Engineering sends validation
complete email to resource owner
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3.2.2 CAISO Certification Responsibilities
The CAISO does not accept real-time telemetry data from a resource unless that telemetry data
is produced by telemetry facilities that have been validated in accordance with the CAISO Tariff
and this BPM.
3.2.2.1
Documentation Requirements
To initiate the submission process in the scheduled FNM build, the resource owner must
provide the following information to the CAISO Generator Connection Project Manager:
 Schematics – For Generating Units, the Generator shall provide one line drawings that
depict the Generating Unit connecting to the grid. Such drawings must be dated, bear
the current drawing revision number and show all wiring, connections and devices in the
circuits. Drawings must be provided for:
 Schematics requirements
Detailed station one-line showing how generators, transformers, aux transformers are
connected, showing all breaker and disconnect names, showing CAISO meter, PT and
CT locations, showing how the station is interconnected to the grid. These schematics
shall be type of released for construction and/or Professional Engineer stamp and
released for construction.
Generator data
 MVA rating
 Rated power factor at PMax
 Nominal terminal voltage
 Reactive power capability curve (limits)
 Terminal voltage control target/range
Transformer data
 MVA ratings (normal and emergency ratings in different seasons)
 Nominal voltages for all terminal sides
 Impedances (listing voltage base and MVA base where the impedance is
calculated)
 LTC data, if applicable
o Max tap and min tap
o Voltage control range
o Tap step size and range
o Normal tap position
Gen tie data
 Line impedance
 MVA ratings (normal and emergency ratings in different seasons)
Breaker data
 if the breaker is normal open, it needs to be shown in the diagram
Aux load
 MW and MVar level
Reactive support devices (shunt capacitor/reactor, SVC, synchronous condenser)
 Rated nominal voltage
 Rated MVar capacity
 Number of banks and size of each bank if it has multiple banks
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BPM for Direct Telemetry
Voltage control target/range

Database submission process

Full Network Model build process

Meter to Point of delivery (POD), where the POD differs from the meter location
 Additional Documentation
3.2.2.2

Map to the site and GPS coordinates

Contact personnel with phone, e-mail address and site address

System Description Overview: An overview should include a brief description one
page or less of the operation of the site. Examples would be the telemetry used and
how it communicates with the CAISO EMS. The size of the Generating Unit and
associated Load should also be included. Other examples include the Point of
delivery of Energy to the CAISO Controlled Grid.

Communication information: Provide the IP address of the telemetry device and all
router ports if using the ECN. Otherwise only the ISP IP address.
CAISO Review of Documentation
If there are any discrepancies between the CAISO RIG Engineering drawings on file and the
actual telemetry installation, then the resource owner or authorized resource owner
representative must document that discrepancy and revise the drawings provided to the CAISO.
Where the resource owner integrator discovers a discrepancy, that person must notify the
CAISO and the resource owner of the discrepancy within 24 hours of the discovery.
If the resource owner doesn’t provide all the required documentation set forth in Section 3.2.2.1
for a FNM build then the CAISO will notify the resource owner. If the documentation that is
required is not delivered within the FNM build time line, the opportunity for the resource to
participate in the CAISO markets will be deferred to the next FNM build time line. The time lines
dates are communicated to the resource owner at the time the Grid Connection Project
Manager receives a request to participate.
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4. Telemetry Standards Overview
Power generation scheduling, control, and real-time monitoring are vital aspects in the
daily operation of the CAISO Controlled Grid and the CAISO Balancing Authority Area.
The CAISO’s EMS simultaneously controls and monitors Generating Unit output to
match resources to load and maintain system frequency. Generating Units offering
Automatic Generation Control (AGC) must be capable of being controlled by the
CAISO’s EMS. The technology that the CAISO has selected for direct communication
with and control of Generating Units is a secure socket layer protocol gateway or RIG
interface system utilizing the Energy Communications Network (ECN), as it meets all
operational and market requirements.
Generators participating in the CAISO Ancillary Services and Energy markets shall meet
technical requirements and standards for real-time communication and direct digital
control established pursuant to CAISO Tariff Section 7.6.1.
The CAISO from this time forward will refer to all real-time communication and control
devices as RIGs and will no longer refer to the Data Processing Gateway (DPG), which
is a concept and name used in prior CAISO real-time data technical standards but which
is no longer needed as a distinction from RIG technology.
5. Communications
5.1 Overview
The CAISO technical operations systems architecture, implemented to carry out
resource monitoring and control, incorporates two central systems comprising the
CAISO’s EMS operating at each of the two CAISO operating locations: Alhambra and
Folsom. The CAISO’s EMS provides AGC and operator dispatch support for monitoring
and control of each resource and provides for the monitoring of the transmission system
within the CAISO Balancing Authority Area.
Technical System Interface Requirement: The Generator shall install a CAISO
validated RIG or comparable CAISO validated system to establish real-time data
interfaces between resource local control systems and the CAISO’s EMS. This is
typically through the CAISO’s ECN to the CAISO’s EMS.
The resource owner can validate its own RIG system to interface with the CAISO’s EMS.
The following is a link to the technical standard document, which is used to validate a
RIG with the CAISO: http://www.caiso.com/2082/2082cdca3ece0.pdf
5.2 Real-time Communications
The CAISO recommends a full ECN T1 circuit implementation. The resource owner
should consider the financial implications of losing a single circuit when evaluating the
cost of redundant circuits.
In general, a single T1 ECN circuit shall be deemed adequate to meet the CAISO’s
communication requirement.
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A 128K ISDN ECN digital dial backup circuit is recommended by the CAISO for primary
circuit backup for all RIG classes. This recommendation is a redundancy for a primary
circuit failure.
A diversely routed secondary T1 ECN access circuit may be optionally implemented on
RIGs equipped with redundant capability and is recommended by the CAISO to enhance
reliability. The CAISO also recommends using redundant circuit paths wherever
possible. The procurement of redundant circuits and paths is the resource owner’s
responsibility.
Resource owners’ systems shall comply with the CAISO’s Security Policy as set forth on
the CAISO Website at http://www.caiso.com/docs/2003/02/18/200302181600117192.html
5.3 ECN Communications Exception
A resource owner participating in the CAISO markets may request as an alternative to
establishing a real-time data interface between resource local control systems and the
CAISO’s EMS through the CAISO’s ECN to install an Internet Service Provider (ISP)
circuit between the RIG and the CAISO’s EMS.
This communication exception can be requested only if the following participation
conditions apply:

The resource is smaller than 400 MW; and

The resource is providing Energy only, with the exception that it may provide
Ancillary Services of Spinning Reserve and Non-Spinning Reserve up to a total
of 10 MW for the resource.

EIR less than 10MW
Note: If a resource owner subsequently decides to participate in the Ancillary Services
markets for more than 10 MW or to participate in the Regulation market, option 3a set
forth in Section 6.3.3 shall be the communication path. The switch to option 3a from an
ISP circuit will require a database build and coordination with a CAISO RIG Engineer.
5.4 Communication Technical Principles
Ping (a computer network administration utility) is a network testing function that shall be
turned on for all ECN connected RIGs and router network ports connecting to the RIG.
5.5 Data Validation and Confidentiality
All telemetry data reported via the RIG must be within +/-2% of the true value.
The CAISO or its designee may inspect the resource owner’s RIG and related facilities
to verify the accuracy and validity of all data telemetry to the CAISO. The CAISO
reserves the right to periodically audit and re-verify the accuracy and validity of all
telemetry data. In addition, the CAISO’s verification activities will be coordinated with
the resource owner at least 24 hours in advance.
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Information transmitted via the RIG from a resource owner to the CAISO will be treated
by the CAISO as the resource owner’s confidential information in accordance with the
CAISO Tariff.
All data telemetry provided through the resource owner’s RIG shall be tested by the
resource owner or resource owner’s representative for accuracy and validity on a
periodic basis as necessary to assure that the accuracy requirements are maintained.
The best practice is to test all resource data annually for accuracy.
5.6 Protocols
The protocol required between the RIG and the CAISO’s EMS is DNP 3 with PKI
security.
RIGs may support a number of standard available plant interface protocols. The
resource owner should contact a validated RIG vendor for more information.
http://www.caiso.com/thegrid/operations/gcp/index.html
5.7 Voice Communications
Each Generator participating in the CAISO’s markets must be able to establish normal
voice communication over a dedicated voice communications circuit from the
Generator’s local control center that has immediate remote and manual control of the
Generating Unit(s).
A dedicated voice communication circuit is one that is available at all times for
communication purposes between the CAISO’s dispatchers and the Generating Unit’s
local control center.
5.8 Communications During Telemetry Failure
Each resource owner participating in the CAISO’s markets and providing real-time data
is responsible to provide communications of generation values to the CAISO on a 24
hour per day, 7 days per week basis until normal telemetry is restored.
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6. Operational Requirements
6.1 Unit Telemetry Visibility
Each resource participating in the CAISO’s Ancillary Services markets or any Eligible
Intermittent Resource or any resource providing Energy with a capacity of 10 MW or
greater that is not exempt pursuant to the CAISO Tariff must provide telemetry data
according to the point matrix specified in Section 7. This BPM will be revised should
additional data points be required, pursuant to CAISO Tariff Section 7.6.1(d).
6.2 Performance Monitoring
6.2.1 Direct Telemetry Timing Requirements
The timing diagram (Figure 1) shows the performance and timing requirements a
Generating Unit connected to the CAISO EMS must meet.

A Generating Unit must be able to accept and begin processing direct digital control
(DDC) signals (Set Point) within the CAISO time standard (two-second maximum
from CAISO’s EMS to output of RIG). The two-second maximum includes any
Generator or “third party” owned communication equipment located between the
CAISO ECN and Generating Unit.

A Generating Unit must be able to send SCADA data to the CAISO within the
CAISO time standard (two seconds from the input of the RIG to the CAISO EMS).

The governor or controller must receive the signal from the RIG within the CAISO
time standard (another two seconds from output of RIG to governor controller).

The time standards also apply in the return direction resulting in a total maximum of
eight seconds round trip for the signal to travel from the CAISO EMS to the
Generating Unit governor controller and back.

The timing requirements from the CAISO EMS to the plant control system (e.g. DCS,
RTU) through the use of non-CAISO communication equipment must meet the
CAISO two second time standard in one direction.

The timing requirements from the plant control system back to the CAISO EMS
through the use of non-CAISO communication equipment must meet the CAISO two
second time standard in the return direction.
6.2.2 PDR Timing Requirements
The provisions of Section 6.2.1 shall apply to PDR telemetry, except that all references
to timing in Section 6.2.1 are increased to one minute.
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Figure 1 - Timing of Telemetered Data for Generators Providing
A/S or Energy Only through the RIG
4 second
maximum
4 second maximum
Unit controls (e.g.
DCS, RTU, etc.
ISO EMS
ECN Cloud
Field
RIG
Unit
Governor
Controller
Generating
Unit
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6.3 CAISO Real-time Communication Options
The CAISO is continually looking for options where resource owners can connect to the
CAISO’s EMS in a cost effective manner. The RIG is defined as a combination of
hardware and software; this combination can be co-located or logically and/or physically
separated to form the RIG as defined by the CAISO. This section will describe multiple
secure options that will allow the resource owner’s control system to connect to the
CAISO’s EMS.
The CAISO’s EMS controls and monitors resource sites from two physical locations.
This exchange of data is performed using RIGs. It occurs over a private, high-reliability,
and high bandwidth communication system, which is the Energy Communications
Network (ECN) established by the CAISO. All communications between the CAISO and
the RIG are accomplished in a secure manner using certificate encryption.
6.3.1
SSL TCP to Serial Data Option
The SSL TCP to serial data communication option consists of a device that performs the
SSL secure connection separately. The plant control system and SSL device functions
as a RIG.
Communication between the plant control system and the CAISO’s EMS is conducted
via DNP 3 protocol; the device that handles the SSL security shall have dual serial
connection to the plant control system unless the serial SSL device has the ability to
manage two logical DNP TCP protocol data streams to one serial connection. A single
serial connection is only acceptable if approved by a CAISO RIG Engineer. The plant
control system shall have a subordinate DNP 3 protocol driver. The data that comes
from metering shall reside in the plant control system.
This option SSL TCP to serial data must pass the CAISO security validation process
located on the CAISO Website at
http://www.caiso.com/thegrid/operations/gcp/index.html (document: RIG Validation
Procedure; section 16). The general data flow of a SSL TCP to serial data option is
depicted in Figure 2.
Appliances that perform SSL TCP connection may be similarly found in network load
balancer devices.
6.3.2
SSL TCP to TCP Clear Text Option
The SSL TCP to TCP clear text communication option consists of a device or software
(software can reside on the plant control system) that performs the SSL TCP secure
connection. The plant control system functions as the RIG pursuant to the standards set
forth in this BPM.
Communication between the plant control system and the CAISO’s EMS is conducted
via DNP 3 protocol. The SSL device handles the SSL TCP security as defined by the
CAISO. The plant control system must have a subordinate DNP 3 protocol driver. The
data that comes from metering shall reside in the plant control system.
This option SSL TCP to TCP clear text must pass the CAISO security validation process
located on the CAISO Website at
http://www.caiso.com/thegrid/operations/gcp/index.html (document: RIG Validation
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Procedure; section 16). The general data flow of a SSL TCP to TCP in-the-clear
hardware option is depicted in Figure 3.
Appliances that perform SSL TCP connection may be found similarly in network load
balancer devices.
6.3.3
RIG Hardware Option
The data communication system consists of two main parts, the RIG and the CAISO’s
EMS.
Communication between the RIG and the CAISO’s EMS is conducted via DNP 3
protocol. This option may be used when a resource owner’s control system cannot
communicate DNP 3 protocol. The RIG hardware is a device that can be validated by
the CAISO to perform all required functions and can be posted on the CAISO Website
as a validated RIG. All posted validated RIGs on the CAISO Website have gone through
the validation process posted on the CAISO Website at
http://www.caiso.com/thegrid/operations/gcp/index.html (document: RIG Validation
Procedure). The general data flow of the RIG is depicted in Figure 4.
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1. Plant Systems: Each plant providing Ancillary Services or Energy has a control
system that can obtain telemetry from Generating Units. Various measured values
will be available from the control system. Included in this BPM are specifications for
the data points required to comply with the CAISO’s standards herein for providing
Ancillary Services or Energy. The plant control system constitutes the source of the
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telemetry necessary to comply with the CAISO’s standards, pursuant to CAISO Tariff
Section 7.6.1(d).
2. SSL TCP to serial or TCP in-the-clear: Has the capability to translate the CAISO’s
EMS real-time IP DNP 3 protocol into serial or TCP in-the-clear DNP 3 protocol at
the resource control system. The CAISO may grant an exemption from the
simultaneous connection requirement for a resource with a capacity less than 10 MW
and that is considered an intermittent resource. The SSL TCP option shall meet the
simultaneous connection standard for a resource with a capacity of 10 MW or
greater. The SSL TCP to TCP in-the-clear can reside on the plant control system.
Plant Interface Protocol: The interface between the RIG device and the plant can
be any protocol convenient to the plant, according to the relationship between the
supplier and the Generator.
3A. ECN Connection: Primary CAISO communication method for the transmission of
telemetry from the RIG device to the CAISO’s EMS is the private communications
network, the Energy Communications Network (ECN). Connection to this network is
obtained by contacting AT&T.
3B. Internet Connection: The internet connection option is for real-time data through an
ISP for the purpose of telemetry.
4. Secure DNP 3 over TCP/IP: The protocol communicated over the TCP/IP transport
is required to be secured DNP 3. Secured DNP 3 is achieved by the combination of
encrypting DNP 3 telemetry over a TCP/IP transport (internet or ECN) using X.509v3
PKI encryption.
5. CAISO EMS: All telemetry arrives at the CAISO’s EMS on the TCP/IP transport via
either the internet or the ECN networks as encrypted DNP 3 protocol.
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6.4 SSL\TCP to Serial or TCP Clear Text Option
The figure 5 identifies, by number, the critical aspects of a serial or TCP clear text
solution. The diagram represents a high-level overview of the perceived functionality of
the solution. It is provided for illustration purposes only. The interfaces that are
envisioned, through abstraction of the internal functionality of the device, are:
1. Plant Control System: Shall perform all the RIG functionality as illustrated herein.
2. DNP 3 Interface: The plant control system shall communicate with DNP 3
subordinate protocol supporting the objects and variations listed herein.
3. PKI Encryption Interface: This layer will be an implementation of SSL using basic
assurance certificates for the CAISO’s ECN or the internet.
4. TCP/IP Interface: The serial to IP device acts as the TCP server/connection. Once
the serial to IP device has requested and established the TCP connection, the
encrypted DNP compatible data stream passes through a TCP/IP connection over a
TCP/IP network.
5. Secure DNP 3 over TCP/IP: Secure DNP 3 data over TCP/IP is achieved when the
encrypted DNP compatible data stream (through SSL) is transported onto the
TCP/IP network.
6. Multi-porting Capability: The SSL TCP device shall have the ability to
communicate to multiple host connections simultaneously over secure TCP/IP
connections at the CAISO’s EMS, which can be up to four simultaneous connections.
For resources with a capacity of less than 10 MW, the CAISO may grant an
exemption from the multiple simultaneous connection requirements for intermittent
resources.
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6.5 RIG Hardware Option
The figure 6 identifies, by number, the critical aspects of the RIG. The diagram
represents a high-level overview of the perceived functionality of the RIG. It is provided
for illustration purposes only. The interfaces that are envisioned, through abstraction of
the internal functionality of the RIG device are:
1. Plant Interface Protocol: The input to the RIG device is a data stream compatible to
the plant systems. This may also be individual hardwired inputs.
2. Internal Plant Interface Protocol Layer: The input data stream is received
internally by an interface layer compatible to the plant systems.
3. DNP Database Profile Specifics: The input data is processed internally in the RIG
as data points in a DNP 3 compatible database structure. Since the RIG must be
DNP 3 Level 1 compliant and could contain a database large enough to require more
than a single data link frame for a Class 0 data response, the RIG must support both
static and event type data points. The RIG is required to support polling by class.
4. DNP 3 Output Interface Layer: As the DNP server, the RIG device will parse all
client requests and supply the appropriate data designated in the aforementioned
point database.
5. PKI Encryption Output Interface Layer: In transferring the data from the RIG to a
destination DNP 3 compatible data, elements are encrypted by a PKI encryption
interface layer. This layer will be an implementation of SSL using basic assurance
certificates for the CAISO ECN or the internet.
6. TCP/IP Output Interface Layer: The RIG is to act as the TCP server/connection.
Once the client device has requested and established the TCP connection, the
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encrypted DNP compatible data stream passes through a TCP/IP interface layer
over a TCP/IP network.
7. Secure DNP 3 over TCP/IP: Secure DNP 3 data over TCP/IP is achieved when the
encrypted DNP compatible data stream (through SSL) is transported onto the
TCP/IP network.
8. Multi-porting Capability: The RIG shall have one TCP/IP address that has the
ability to communicate to a multiple secure connections at the CAISO’s EMS that can
be up to four simultaneous connections.
6.6 CAISO’s EMS Interrogations:
The CAISO’s EMS DNP front-end processors interrogate each RIG with DNP Object 60,
Variations 2 for event data polling (class 1 data). Responses shall be the event objects and
variations listed below.
The CAISO’s EMS DNP front-end processors interrogate each RIG with DNP Object 01
Variation 00 “digital static updates” and Object 30 Variations 00 for “analog static updates.” The
response shall be the Static Objects and Variations listed in Section 6.7 below.
6.7 RIG Responses DNP Object and Variation Types
Objects and Variations supported by the RIG device must include, but are not limited to:

Static:
Object 1 Variation 2 (Digital)
Object 30 Variation 2 (Analog)

Event:
Object 2 Variation 2 (Digital)
Object 32 Variation 2 (Analog)

Time:
Object 50 Variation 1 (read and write)

Control:
Object type 41 (analog setpoint) Variation 2
Important
The CAISO’s EMS DNP front-end processors will utilize other DNP group and variations, other
than listed above. All RIG solutions must be DNP 3 Level 1 certified.
Deadband: Analog events should be set to .5 Engineering Units. The deadband must be
configurable on a point-by-point basis. Exception for the analog deadband is analog points
associated with wind, solar, and PDR resources. These types of resources have a much
smaller deadband requirement and higher resolution. Please consult a CAISO RIG Engineer for
proper deadband settings.
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6.8 Quality Flag Propagation to DNP
When a resource owner installs a RIG and it communicates to downstream devices that are not
directly connected to the RIG, the originating device(s) shall propagate a data quality
communication flag for each point to the RIG through each non-originating device. A data port
alarm point may not be required; however, this will be determined by CAISO RIG Engineering.
Other protocols with data quality flags maybe used to propagate flags into DNP flags (i.e., OPC
(object linking and embedding for process control)).
An originating device is one that gathers field data directly (for inputs) or issues controls directly
to the field (for outputs). A non-originating device is one that obtains input data or issues control
commands via a communications link from originating or non-originating devices. A reporting
device is a device that acts as a DNP3 outstation, sending DNP3 messages to an upstream
device.
Data from an originating device may arrive at the master via one or more data concentrator
devices. In this case, each device in the communications chain, other than the master, is a
reporting device. This identification of various devices is illustrated below. The terms
“upstream” and “downstream” that indicate relative device hierarchy are also shown in this
diagram.
A COMM_LOST indicator indicates that there is a communication failure in the path between
the device where the data originates and the reporting device on a point to point basis. This flag
indicates that the value reported for the object may be stale or in bad quality. If set, the data
value reported shall be the last value available from the originating device before
communications were lost.
An originating device never sets this flag. A non-originating or master device sets this flag if it
loses communication with the adjacent downstream device; otherwise it propagates the state of
COMM_LOST flag as received from the downstream device. Once set, this flag may only be
cleared when data for this point is received from the adjacent downstream device and the
COMM_LOST flag received with that data is cleared.
6.9 Maximum MW RIG Limitation
The CAISO’s grid and market operations depend on RIG data to reliably run real-time
operations, the Full Network Model, and the State Estimator. To minimize potential impact to
the CAISO’s grid and market operations, the CAISO sets a maximum MW limitation. The
limitation is set to protect the CAISO’s markets and grid, should a RIG failure occur.
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The maximum generation that can be put on a single RIG cannot exceed 1200 MW from a
physical location. This includes the ECN circuit and router. The CAISO reserves the right to
review all proposed telemetry systems for compliance with this and other RIG limitations.
For Eligible Intermittent Resources and RIG Aggregators, the maximum combined generation
for a single RIG (including the ECN circuit and router) is 400 MW.
6.10
RIG Location Requirements
The purpose of a RIG location requirement is to limit the impact of possible RIG failures to a
smaller geographical area. Location limits are defined by the standard 23 Sub-LAPs within the
CAISO Balancing Authority Area. The location limitation provides that only resources within a
Sub-LAP can be aggregated within a RIG. The RIG shall reside within the Sub-LAP for the
resources it is aggregating.
The CAISO can make an exception to the location limits for aggregating resources within a RIG
if a resource is located in an adjacent Sub-LAP that does not have a RIG.
A RIG Aggregator can combine multiple physical resource locations within a Sub-LAP. The MW
limitation and limitation of aggregation location to Sub-LAPs is due to the unpredictable nature
of these resource types (i.e., solar and wind). Only a CAISO RIG Engineer may authorize an
exception to location limits. The list of the Sub-LAPs is set forth in Section 19.
These limitations do not apply if a RIG Aggregator desires to transmit real-time data to the
CAISO for information only. The RIG location limitations do not apply to RIGs used in the
transmission of real-time data by Demand Response Providers (DRP) to the ISO for Proxy
Demand Resources.
6.11 RIG Resource Limitation
The purpose of a resource limit is to mitigate the impact of a RIG failure on the CAISO’s State
Estimator. If the CAISO loses communication with many resources at once, it may impact the
CAISO’s modeling calculations. To mitigate this risk, the CAISO has set the resource limit for a
single RIG to 25 Resource IDs, subject to the defined MW limits set forth in Section 6.9 above.
6.12 Cost Responsibility
Each resource owner will be responsible for all costs incurred for RIG procurement and
installation for the purpose of meeting its obligations under this CAISO BPM, notwithstanding
other CAISO policies, procedures, and contracts that may affect the distribution of costs to
participating parties.
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7. Telemetry Data Points List
The following values are the minimum requirements for real-time visibility of each
resource. The CAISO’s Operations & Engineering groups have approved these
requirements. They are the minimum standards that will allow the CAISO to manage
effectively the reliability of the grid. At any time, the CAISO may require additional points
to be added to meet real-time requirements. The following points must be provided for
each resource in the specified category. The resource owner must obtain the required
point list from a CAISO RIG Engineer.
7.1 Point Matrix
The following pages represent the minimum point requirement matrix for each type of
RIG configuration that the CAISO requires for real-time control or monitoring. The matrix
specifies the telemetry points required for the following categories of resources:
AGC: Resources certified to provide Regulation in the CAISO Markets.
Spinning Reserve: Resources certified to provide Spinning Reserve in the
CAISO Markets.
Non-Spinning Reserve: Resources certified to provide Non-Spinning Reserve
in the CAISO Markets.
QF Conversion: Resources that are Qualifying Facilities not exempt from
CAISO Tariff telemetry requirements pursuant to pre-existing agreements. Note
that MW, MVAR, and voltage values are measured based on the Point of
Demarcation for a Net Scheduled QF subject to a QF PGA.
Energy Only: Resources that provide Energy only.
PDR: Proxy Demand Resources.
Solar: Solar resources.
Wind: Wind resources.
If a resource falls within more than one category, the resource owner or RIG Aggregator
must provide the telemetry points specified for each applicable category.
Section 17 has the detailed definitions for the following point matrix.
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AGC
Spinning
Reserve
NonSpinning
Reserve
Unit Gross MW
Unit Net MW
Unit Point of delivery MW
Unit Auxiliary MW
Pseudo Gen MW
Bias Load MW
Unit Generator Terminal Voltage
Unit Gross MVAR
Unit Net MVAR
Point of delivery MVAR
Auxiliary MVAR
Capacitor Bank VAR
High\Line Side Bank MW
High\Line Side Bank MVAR
High\Line Side Bank Voltage
X
X Note1
X
X Note2
X
X Note1
X
X Note2
X
X Note1
X
X Note2
Aggregated Gross MW
Aggregated Net MW
Aggregated Point of delivery MW
Aggregated Gross MVAR
Resource ID Setpoint Feedback
RIG Heart Beat
Analogs
QF
Conversion
X Note9
X Note1 & 9
X
X Note2 & 9
Energy
Only
X
X Note1
X
X Note2
PDR
X
Note10
Solar/Wind
less than
10MW
Solar
Wind
X
XNote1
X
XNote1
X
X
X
X
X
XNote3
X
XNote3
X
X
X
X
X
X
XNote12
X
X
X
X
X
X
X
X
X
X
X
X
X Note3
X
X Note4
X
X
X Note3
X
X Note4
X
X
X Note3
X
X Note4
X
XNote9
X Note3 & 9
X
X Note4 & 9
X
X
X Note3
X
X Note4
X Note5
X Note5
X Note5
X Note5
X Note5
X Note5
X Note5
X Note5
X Note5
X Note5
X Note5
X Note5
X Note5
X Note5
X Note5
X Note6
X Note6
X Note6
X Note6
X
X
X Note6
X Note6
X Note6
X Note6
X Note6
X Note6
X Note6
X Note6
X Note9
X Note9
X Note6
X Note6
X Note6
X Note6
X Note6
X Note6
X
X
X
X
X
Note10
X
X
Continued to next page
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Analogs
AGC
Aggregate\Unit Operating High Limit
Aggregate\Unit Operating Low Limit
Wind Speed (Meter / Second)
Wind Direction (Degrees - Zero North 90CW)
Air Temperature (Degrees Celsius)
Barometric Pressure (HPA)
Back Panel Temperature (Degree C)
Plane Of Array Irradiance Watts\Meter Sq.
Global Horizontal Irradiance Watts\Meter Sq.
Direct Irradiance Watts\Meter Sq.
Diffused Plane Of Array Irradiance Watts\Meter Sq.
Diffused Global Horizontal Irradiance Watts\Meter Sq.
Reference Cell (MW @ .001 resolution)
Spinning
Reserve
NonSpinning
Reserve
QF
Conversion
Energy
Only
PDR
Solar
Wind
X
X
X
X
X Note11
X Note11
X Note11
X Note11
X Note11
X Note11
X Note11
X
X
X
X
Solar/Wind
Less than
10MW
X
X
X
X
X
X
X Note11
X Note11
X Note11
X Note11
X Note11
X Note11
X Note11
Continued to next page
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Digitals
Unit\Resource Connect
PDR Resource Connect
Power System Stabilizer
Automatic Voltage Regulator
Capacitor Bank Breakers
Unit Low Side Breaker
Related Unit Breakers
Related Unit MOD's Disconnects
Data Port Alarms
Switchyard Line Breakers (if Generator Owned)
Switchyard Line MOD (if Generator Owned)
Aggregated\Unit Connected
Aggregated\Unit Authority Switch
Aggregated\Unit Control Switch
Aggregated\Unit Automatic Generation Control
Aggregated\Unit Ready To Start
Aggregated\Unit Start
AGC
X
Spinning
Reserve
X
NonSpinning
Reserve
X
QF
Conversion
X
Energy
Only
PDR
X
Solar
X
Wind
X
X Note 7
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Solar/Wind
Less Than
10MW
X
X
X Note 7
X Note 7
X Note 7
X Note 7
X Note 7
X Note 7
X Note 7
X Note 7
X Note 7
X Note 7
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X Note6
X Note8
X Note8
X Note8
X Note6
X Note6
X Note6
X Note6
X
X
X
XNote13
X
X
Note6
X
X
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7.1.1 Analog and Digital Notes
1.
2.
3.
4.
5.
6.
If Aux MW are over 1 MW then Net MW are required.
Required If Aux MW are over 1 MW.
If Aux MW are over 1 MW then Net MVR are required.
Required if Aux MW are over 1 MW.
Transformer High Side or Line values required depending on meter location.
Provide Unit Connected and Gross MW for each unit and aggregated values if
Resource ID is an aggregate. Individual POD not required if the Resource ID is an
aggregate.
7. PSS \ AVR indication is needed if plant is required to install these devices.
8. Required point for each Resource ID.
9. Required if the QF is not subject to a QF Participating Generator Agreement.
10. Resolution @ .001 Gross MW = POD.
11. See the Solar Meteorological Data Tables in Section 13.5 and definitions of data
points in Section 17.4. Note that some data points are not required from solar
thermal facilities.
12. Voltage from CAISO meter at metering point
13. This does not have to be an actual circuit breaker but an indication from some
device within the system showing when the resource is physically connected or
disconnected to the grid. One point only per resource
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8. Availability & Maintenance
8.1 CAISO Reliability Requirements
The resource owner shall be responsible for maintaining the availability of the RIG, all
RIG interface systems, and RIG communications access to the ECN.
The RIG (including all parts thereof) is and will at all times remain the property of the
resource owner. Risk of loss, theft, or damage of the RIG will be the responsibility of the
resource owner.
A resource owner will be solely responsible, at the resource owner’s cost, for preparing
and maintaining the site at which a RIG will be installed, and for engineering, installation,
operation, and maintenance of that RIG and all other activities associated with the
installation, operation, and maintenance of that RIG; except that this provision does not
supersede agreements addressing responsibility for costs of engineering, design,
installation, and testing set forth in any agreement for the installation of a RIG. The
CAISO will provide support as described herein to ensure that the RIG properly
interfaces with the CAISO’s EMS.
The local communications access circuit generally represents the highest risk to plant
interface availability. Proper engineering of circuit pathways with alternate paths and
redundancy wherever feasible is recommended. In all cases, the CAISO recommends
that the resource owner consider implementation of an ISDN digital dial backup circuit at
a minimum to maintain communications.
An owner of a RIG is responsible for:





Meeting the CAISO security requirements
Acting as the main point of contact for any data quality issue.
Ensuring the accuracy of the data transmitted to the CAISO.
Resolving any data quality issues identified by the CAISO.
For a RIG Aggregator, see Section 15.
8.2 CAISO Controlled Grid Operation and Market Availability
Requirement
A resource owner will be solely responsible for all costs and other consequences
associated with the unavailability of the RIG and the inability of the RIG to communicate
with the CAISO’s EMS, including any financial consequences pursuant to the terms of
the CAISO Tariff. Such failure may result in penalties for failure to perform in
accordance with the terms of the CAISO Tariff. Additionally, the resource owner’s
certification to provide Ancillary Services may be affected in accordance with the
provisions of Sections 8.9 and 8.10 and other provisions of the CAISO Tariff.
8.3 RIG Operation and Maintenance
The resource owner is responsible for all activities associated with the operation and
maintenance of the RIG. The purpose of this section is to describe the notification and
interface requirements for the following activities.

Software Upgrades
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

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Data Base Revisions
Routine Testing/Maintenance
The diagram below illustrates the boundaries of responsibility for maintenance of the
system from the CAISO to a Generating Unit. Sections of the system are illustrated with
responsibility assigned to either the CAISO or the Generator. The CAISO is responsible
for the maintenance of the CAISO’s systems, such as the EMS and the SCADA
equipment interfacing to the ECN. The CAISO’s ECN contract provider has
responsibility for maintaining the ECN through contract to the CAISO. The CAISO, as
the organization securing the services of the CAISO’s ECN contract provider, has
accountability for the maintenance of the ECN. The Generator has the responsibility of
operating and maintaining the plant systems, the RIG, and the communication circuit
connecting to the ECN.
Figure 7 Operation and Maintenance Boundaries
Plant
Metering
Control
System
Energy
APOP
ECN
RIG
Generator O&M
Management
System
ISO ECN Contract
Provider O&M
ISO O&M
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8.3.1 Software Configuration Management with No Impact to CAISO EMS
The intent of the following requirements is to provide a notification and approval
process for the installation of software upgrades requested by a resource owner
or required by the CAISO, based on the understanding that overall functionality
of the system shall be ensured through consistency of software and software
upgrades.
Each resource owner must safeguard the RIG software and treat it as its own
confidential business property, but in no event may it use less than reasonable
care to protect the confidentiality of the RIG software. Each resource owner
must ensure: (i) that neither it nor any person having access to the RIG will
attempt to modify or reverse engineer the RIG software; and (ii) that it takes
reasonable steps to ensure that all persons having access to the RIG will
observe the resource owner’s obligations relating to the RIG.

The CAISO maintains a database spreadsheet for each RIG that contains the
required data points from the plant information data acquisition point list
contained herein. The RIG database spreadsheet may also contain
additional data as required for mapping to the CAISO’s EMS. In order to
maintain operation of the EMS, the CAISO requires prior notification and
approval of all revisions to the RIG database spreadsheet. The resource
owner must obtain the latest spreadsheet revision from a CAISO RIG
Engineer before making modifications to the spreadsheet. A resource owner
may make modifications to its RIG to support its operations, including the
addition of data input/output points, which may not be made available to the
CAISO, and the addition or replacement of hardware, as required to
accomplish the resource owner’s purposes, provided that the resource owner
must coordinate any modification of the RIG database spreadsheet with the
CAISO and will be solely responsible for all costs and other consequences
associated with the performance and/or unavailability of the RIG and/or the
inability of the RIG to communicate with the CAISO’s EMS, including any
financial consequences pursuant to the terms of the CAISO Tariff, as a result
of any such modifications. The resource owner shall notify the CAISO at
least seven days prior to any database spreadsheet revision. The resource
owner shall submit a database revision for review by a CAISO RIG Engineer
that clearly states the proposed database changes, including the revision and
installation date and a valid SLIC Outage number. Following CAISO approval
of the database revision request, the resource owner shall adhere to the
requirements contained herein during the installation of the new database.
The resource owner shall notify the CAISO before installation of the new
database and participate in joint testing with the CAISO prior to placing the
RIG back in service.

The resource owner may at times require a software upgrade from the RIG
vendor that has no impact on the CAISO EMS database. In order to ensure
these activities do not impact the CAISO’s EMS at the Folsom and Alhambra
facilities, the CAISO requires prior notification and approval of all vendor
software upgrades to the RIG. The resource owner shall notify the CAISO at
least seven days prior to any software upgrade installation, and provide a
valid outage number that clearly covers the software upgrade. Should the
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CAISO approve the software upgrade installation request, the resource
owner shall adhere to the requirements contained herein during the
installation of the new software; as well the resource owner shall follow all
Outage Coordination process in accordance with the CAISO Tariff. The
resource owner shall notify a CAISO RIG Engineer before installation of the
software upgrade.
Outage Coordination internet address:
http://www.caiso.com/docs/2001/02/01/2001020108211325518.html
8.3.2 Data Base Configuration and Management Impacting CAISO EMS
The intent of the following requirements is to provide a process for RIG database
changes

The CAISO or the resource owner may make modifications to the CAISO’s
EMS functionality, software, or database. The CAISO will notify each
affected resource owner 120 days in advance of any such modification and
will provide a detailed explanation of the modifications that will be made. The
resource owner may require changes to the RIG database that impact the
EMS database and shall contact a CAISO RIG Engineer 120 days in advance
of requested change. In such event, the resource owner will be responsible
for making any necessary conforming changes to the RIG to maintain the
interface with the EMS. The CAISO will work with the affected resource
owner to stage the work, such that no Generating Unit will be impacted in its
ability to provide Regulation due to the unavailability of the human resources
required to accomplish the changes. No such modifications may compromise
the resource owner’s right or ability to restrict access to information
associated with the resource owner’s resources by any party, as provided
herein.
8.3.3 Routine Testing/ Maintenance of RIGs
Each resource owner will remain solely responsible for the completeness and
accuracy of all information transmitted by the resource to the RIG. The CAISO
will not be responsible for the quality of the data transmitted through the RIG and
will only validate that information for accuracy. The CAISO and the resource
owner will monitor the resource owner’s data transmitted through the RIG and,
upon observation of any problems with that data, must provide the other party
notice of that problem and must work together to correct the problem.
The resource owner is responsible for all routine testing and maintenance of the
RIGs. The intent is to provide resource owners with the process to follow in
order to maximize RIG operation while periodic maintenance and/or testing is
performed. Minimizing the loss of RIG communication, and thereby minimizing
the period when a resource is unavailable for bidding in the Ancillary Services
markets, is in the best interest of both the resource owner and the CAISO. The
resource owner must also avoid sending spurious or inaccurate data through the
RIG as a result of testing and maintenance activities without first coordinating
test plans and actions with the CAISO. Spurious and inaccurate data sent
through a RIG to the CAISO and which the CAISO is not expecting to receive will
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impact the CAISO’s real time Balancing Authority Area load and reserve
requirements calculations and its markets.
Scheduling
Planned periodic maintenance and/or testing of the RIGs must be scheduled with
the CAISO at least 72 hours in advance with a valid SLIC Outage number from
the CAISO Outage Coordination Office.
Planned periodic maintenance and/or testing of the RIGs should be performed
during resource Outages whenever possible.
Loss of RIG communication will result in the inability of the resource to participate
in the Ancillary Services markets.
For a resource having seven consecutive and/or nonconsecutive calendar days
of failed communications or failed required telemetry data, the CAISO will send a
letter to the Scheduling Coordinator. If the compliance issue is not resolved
within 30 days, the CAISO will send an additional letter to inform the resource
owner and Scheduling Coordinator that the resource’s ability to participate in the
Energy market or Ancillary Services markets may be removed.
Outages shall be requested through the resource’s Scheduling Coordinator, and
planned RIG work should only take place between 8:00 am and 4:00 pm Monday
through Friday, excluding CAISO holidays.
Outage Coordination internet address:
http://www.caiso.com/docs/2001/02/01/2001020108211325518.html
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9. RIG Implementation
9.1 Engineering / Deployment
The resource owner is responsible for all procurement, engineering services, and
maintenance with regard to the installation of the RIG. The CAISO suggests that the
first step in the installation process be that the resource coordinates a “kick off” meeting.
9.2 RIG Database Development
The CAISO’s RIG Engineer will provide technical assistance as required to the resource
owner during the RIG hardware selection process. The CAISO’s RIG Engineer will also
provide assistance during the development of the RIG database.
9.3 Telecommunication Circuit Installation and Power
Requirements
The resource owner may obtain ECN access circuit(s) from the ECN contract provider.
The ECN contract provider will typically utilize a local exchange carrier (LEC), to provide
last-mile cable service to a plant from an ECN point-of-presence (POP) facility location.
The LEC is responsible to provide the circuit to the plant main point of entry (MPOE)
only. It is the resource owner’s responsibility to provide for, or contract services for, the
implementation of high voltage protection (HVP) for these circuits where required. HVP
is highly recommended by the CAISO and required in cases where the LEC requires
high voltage protection unless fiber optic cabling is used. It is also the resource owner’s
responsibility to provide on-site extension of the ECN circuit(s) to the actual RIG cabinet
location on-site, preferably by fiber optic cabling.
All service power to communication equipment and the RIG must be powered by an
uninterruptable power supply (UPS) for the same amount of time the LEC is providing.
This is not limited to RIG router, fiber optic power on both ends of the cabling, and
Channel Service Unit/Data Service Unit (DSUCSU). Any communication equipment and
device providing real-time communications to the RIG (i.e. CAISO revenue meter) shall
install a UPS or equivalent. For Eligible Intermittent Resources, see Section 13 (Power
Reliability Requirements).
9.4 Temporary Telemetry Exemptions
The CAISO may grant a temporary telemetry exemption for a resource that is new to
participation in the CAISO’s markets, but an exemption is not guaranteed. The
exemption is used for a resource owner that is unable to comply with applicable
telemetry requirements prior to the transition of its resource to commercial operations in
the CAISO’s markets.
Temporary telemetry exemptions are focused on particular data. A resource owner must
provide all required documentation in order to submit a request for a telemetry
exemption.
More information regarding the CAISO’s telemetry exemption process can be found at
the following location on the CAISO Website:
http://www.caiso.com/thegrid/operations/gcp/index.html
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10. FNM Database Process and RIG Installation
The FNM database process and RIG installation for real-time telemetry data section references
the required steps for new and existing RIGs entering or maintaining the installation.
10.1 CAISO FNM Database Process
Section no longer required, replaced with New Resource Implementation Timeline at
http://www.caiso.com/participate/Pages/Generation/Default.aspx under section Process and
requirements
10.2 New Database Submission
Standards in order to submit a RIG database for a CAISO database build
Section no longer reqired, replaced with New Resource Implementation Timeline at
http://www.caiso.com/participate/Pages/Generation/Default.aspx under section Process and
requirements.
10.3 RIG Database Submittal Timeline

Section no longer required, replaced with New Resource Implementation Timeline at
http://www.caiso.com/participate/Pages/Generation/Default.aspx under section Process and
requirements.
10.4 ECN Physical Circuit Protection to the Resource

Copper installation at your de-mark
o High voltage protection (HVP) may be required by the local exchange carrier
(LEC)
o Longer lead time (up to 90 days)

Fiber optic installation at the de-mark
o Shorter lead time (30 to 60 days)
o No HVP required in most cases
10.5 ECN Circuit Monitoring

AT&T
o

AT&T provides 24/7 router and circuit monitoring with same-day technician
dispatch.
Other circuit monitoring
o Resource owners can provide or contract their own monitoring of the ECN circuit.
o Resource owners are responsible for resolving ECN circuit problems.
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10.6 ECN Agreement

The resource owner must sign the ECN agreement and mail it to the CAISO before the
communication from the CAISO’s EMS is opened and testing can be scheduled. The
CAISO may accept an e-mailed version of the signed ECN agreement on a case-bycase basis, conditional on subsequent receipt of a hard copy.

Network Connectivity Security Requirements and ECN agreement are posted on the
CAISO Website at the following link:
http://www.caiso.com/docs/2001/09/26/2001092611012525611.pdf

The following is the address to which the resource owner is required to send the hard
copy of the signed ECN agreement:
CAISO
250 Outcropping Way
Folsom, CA 95630
Attn: RIG Engineering
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10.7 Standards For Point-to-Point Testing with the CAISO
Before a resource owner submits a request to test its RIG installation, the resource owner must
pretest all data points to a DNP master simulating the CAISO connection without security prior
to the scheduled test date. This pretest is to assure quick testing with the CAISO.
The resource owner has the responsibility to validate and notify the CAISO that the DNP
protocol point to point pretesting has been completed by either email sent to
[email protected] or letter sent to the address earlier in this section. Without this notice,
the schedule test date may be canceled.
Methods of Pretesting:



DNP master emulator
DNP master test set
Other DNP software capable of polling the RIG
Additional RIG configuration needed before final testing can be performed:


Device PKI certificates installed
Review documentation provided by CAISO RIG Engineering
It is essential that pretesting is done with the plant control system and revenue metering through
to a DNP master simulation before testing with the CAISO. Manipulation of real-time data at the
RIG is not an acceptable method of testing.
Testing of Points





Each analog point shall be tested to full, mid, and low scale. CAISO RIG Engineers at
their discretion may allow other values.
Each digital point On and Off state verified.
Calculated points shall be tested by changing inputs to the calculation.
Set Points will be tested to full, mid, and low scale.
Each port alarm shall be tested. With each port alarm a subset of analog and digital
telemetry Online\Offline flag is set appropriately.
Revenue Meter Real-time Point Testing for a New RIG Installation:

The meter analog points shall be tested with a test set by injecting voltage and current to
the meter.
Revenue Meter Real-time Point Testing for an Existing RIG Installation:

A synced resource or a meter test set may be used to verify the real-time values.
Point testing with the CAISO shall be undertaken as the last part of the testing and
installation phase.
The resource owner has the responsibility to have all pre-testing completed before
scheduling CAISO testing. If not, a delay or rescheduling of CAISO testing may be
required.
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10.8 Required Personnel for Point testing

At the scheduled RIG testing date, the following personnel are needed for testing:
o Resource personnel capable of exercising each real-time point required to be
sent to the CAISO’s EMS from the resource control system through the RIG.
o Integrator responsible for the RIG installation.
o Revenue meter personnel who can inject test values into the meter to verify realtime data going to the CAISO’s EMS through the RIG. The CAISO may make an
exception to this requirement for an operating resource if it does not include new
generation.

Testing from the RIG to the CAISO’s EMS alone is not considered sufficient for a CAISO
point test (i.e., plant control system to RIG to CAISO’s EMS).
The final CAISO test will be complete at the parallel of the resource.

10.9 Upgrade or Replacement RIG
Standards of replacing, upgrading, or modifying an existing RIG device
o
o
o
o
o
o
o
10.10
The resource owner must submit a SLIC Outage for some time during the period
Monday-Friday between 8:00 a.m. and 4:00 p.m. only. The existing RIG must be
returned to service after 4:00 p.m. daily.
The resource owner must provide 72 hours lead time for scheduled testing times.
A third-party engineering firm may not request the existing RIG spreadsheet
directly from the CAISO. The CAISO must receive an e-mail from the resource
owner granting permission for the CAISO to provide the spreadsheet to the third
party.
The CAISO will verify the request with the resource owner.
The CAISO will only give IP addresses to the resource owner, unless directed
differently.
All other point testing discussed previously is required.
If the resource is operating, generally, calculated points (UCON) cannot be
tested. These points will be verified when the resource shuts down.
SLIC Outage for Meter or RIG work
The CAISO RIG Engineering group will not approve any work on a RIG or CAISO revenue
meter without a verified SLIC outage.
The plant personnel will need to call the CAISO RIG Engineering group before work is
started.

Before the plant personnel calls, they must verify that:
o The SLIC outage has a valid SLIC number.
o The SLIC # is for the actual times, work, and equipment being performed.
o The SLIC # Outage has been started and the OUT (Active) state.
o The call is made to CAISO RIG Engineering, 916-608-5897
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PM for Direct Telemetry

Plant\Genera
P
ator person
nnel coordin
nates all wo
ork for:
o Third Party Meterr Engineers: They are to call the CAISO RIG Engineering grroup
at the number abo
ove before removing a m
meter out of service.
o RIG In
ntegrators: They
T
are to call
c the CAIS
SO RIG Eng
gineering gro
oup at the
number above be
efore starting
g work on a R
RIG.

What
W
CAISO
O RIG Engineering is no
ot responsi ble for:
o Subm
mitting the SL
LIC outage.
o Startin
ng the SLIC outage.
o Obtain
ning the SLIC outage nu
umber.
o Calling all the parrties respons
sible.
g the SLIC to the OUT (active) state
e.
o Taking

CAISO
C
RIG Engineering
E
g Action witth a SLIC O utage.
o Call th
he CAISO Real-Time
R
Op
perator befo re work starrts.
o Call th
he CAISO’s service centter (SMSC) about the pe
ending workk.
o Lock down
d
the res
source’s currrent MW ou
utput for the FNM and EM
MS load
calculation, and coordinate with the plant personnel tto keep value
es current during
the ou
utage.
P
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10.11
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RIG Certificates
The resource owner must meet the following requirements to obtain a CAISO RIG
certificate:

New Installations
o Indicate in an e-mail to CAISO RIG Engineering containing the request form and
certificate file that the request is for a new installation.
o Obtain the common name from CAISO RIG Engineering either by e-mail or
phone (916) 608-5897.
o Copy the CAISO RIG Engineers on all certificate requests at
[email protected]

Existing RIG
o The CAISO will verify with the resource owner if a certificate request comes from
a third-party entity.
o The CAISO will inquire from the resource owner the intended party that will be
installing the renewed certificate.
o Copy the CAISO RIG Engineers on all certificate requests at
[email protected]

All Certificate Requests
o There is a minimum ten-day lead time for all certificate requests.
o All certificate requests must include a device request certificate form and
certificate file.
o The device request form can be found on the CAISO Website at
http://www.caiso.com/pubinfo/info-security/certs/. The requester should access
that website and open the Excel Device Certificate Request Form.
o The resource owner must e-mail a complete certificate request to
[email protected] and to [email protected].
o The resource owner must obtain a SLIC outage for the installation of the new
certificate.
o The resource owner must inform CAISO RIG Engineering of the scheduled SLIC
outage a minimum of two weeks before existing certificate expires.
o CAISO RIG Engineering shall not be responsible for the timing of the renewal
request sent to the CAISO certificate request e-mail address.
o The RIG certificate can be installed on an end device as soon as it is received by
the intended party. As specified above, the resource owner must obtain a SLIC
outage and schedule the installation with CAISO RIG Engineering before
installing the certificate.
o CAISO RIG Engineering will diligently inform each resource owner of the end
date of its RIG certificate. CAISO RIG Engineering will provide the resource
owner notification by phone and e-mail at least two months in advance of each
certificate deadline. However, resource owners should be aware of certificate
expiration dates.
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10.12
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RIG Generation Acceptance Test
The resource owner must provide the CAISO documentation confirming a successful RIG
Generation Acceptance Test (RGAT).
o
10.13
This documentation should not be considered a payment milestone for a
resource owner’s third-party engineering firms.
 These documents are not a requirement to deliver power, which will
come from the CAISO Implementation Project Manager.
 The content of this documentation must be completed and signed off.
 These documents are not required to be signed immediately after a
successful end-to-end test with the CAISO.
 Plant personnel involved or knowledgeable with the installation of the
RIG are required to sign these documents.
 The resource’s CAISO RIG Engineer will typically visit the resource
site for signature by the resource owner and to answer any questions.
Alternatively, the CAISO RIG Engineer may send an electronic copy
of the RGAT for signature.
 CAISO RIG Engineering Website:
http://www.caiso.com/thegrid/operations/gcp/index.html
Final RIG Documentation
Final RIG documentation is a required piece of a larger package delivered to the CAISO’s Grid
Operations group. In order to transfer a resource that was in a construction phase to a
production connected resource, Operations requires particular sets of information documenting
that all CAISO functionality has been tested and verified. This assures Operations that the site
is visible and ready for production. CAISO RIG Engineering needs the following items from the
resource owner in order to complete the RIG Engineering piece of the whole package sent to
CAISO Operations:

Site contact spreadsheet completely filled out and shall include:
 24/7 site contact number (typically the control room phone number)
 Technical RIG personnel phone numbers and e-mail addresses
 Resource owner phone numbers and e-mail addresses
 As built RIG database spreadsheet.
 Final revised version of the Excel database spreadsheet provided by the CAISO RIG
Engineering group at the start of the project.
 Resource site narrative document. This document will describe the overall resource and
project. Examples are available upon request.
These required documents are in addition to all other documentation required by this BPM.
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Wind and Solar FNM Documentation Required
The following additional items must be provided by the resource owner for wind and solar
resources that are EIRs:


Site Map (-15B)
o Longitude, latitude, and elevation of all meteorological towers and hub height of
all turbines. List of Designated Turbines for wind resources. Refer to Section 13
for additional detail information.
 Approved by the forecast service provider and Generator.
o Topographical map of the wind farm turbine layout. Refer to Section 13.4.3 for
detailed map information.
Additional Requirements for Solar Resources (-15B)
o Identifying the type of solar resource, i.e., photovoltaic, solar concentrator, etc.
o Type of inverters used (for modeling purposes)
 Inverter states (off, standby, start)
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11. AGC Operational Requirements for Generating Units
11.1 Required DNP and Telemetry Data Points for AGC
To meet the minimum requirement of real-time visibility for Generating Units providing
Automatic Generation Control (AGC) to the CAISO, each RIG must be capable of
communicating the following types of values to/from the CAISO’s EMS:



Analog input values to the CAISO
Digital input values to the CAISO
Analog output (Set Points) from the CAISO
To meet the minimum requirement of real-time visibility for Generating Units providing
Automatic Generation Control (AGC) to the CAISO, each RIG must be capable of
communicating the following telemetry data points to/from the CAISO’s EMS:







Unit Control Switch (UCTL)
Unit Authority Switch (UASW)
Automatic generation control (UAGC)
Automatic generation control Set Point
Automatic generation control feedback
Unit Operating High Limit (UOHL)
Unit Operating Low Limit (UOLL)
For a detailed description of the minimum data point requirements for Generating Units
providing AGC Regulation to the CAISO please refer to Section 17.
The CAISO Operations and Engineering groups have approved the list of data point
requirements described herein. They are the minimum data point standards that will allow
the CAISO to manage effectively the reliability of the grid. At any time, the CAISO may
require additional telemetry values to meet real-time operational requirements.
11.2 AGC Control (Bumpless Transfer)
For resources providing AGC, the RIG may have the option to set up a bump less transfer
method for AGC control, to track Set Point when resources are off AGC control. A
calculated Set Point will be stored in the RIG, continually updating with the current MW
value of the resource. When the resource transfers to AGC control, and starts accepting
valid Set Points, the calculation will deactivate. The calculation should only reactivate when
AGC control is disengaged.
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12. Non-Spinning Reserve Logic and Testing
12.1 Non-Spinning Reserve Definition
Non-Spinning Reserve is defined in the CAISO Tariff. In essence, it is off-line generation
capacity that can be synched to the grid and ramped to a specified load within 10 minutes of
a Dispatch Instruction by the CAISO, and that is capable of maintaining that output for at
least 30 minutes.
The following is the testing and functionality that will be required prior to Non-Spinning
Reserve certification. For further information and requirements for Ancillary Services, see
http://www.caiso.com/docs/2005/10/05/2005100520285623168.html
12.2 Non-Spinning Reserve Logic Requirements
In order to bid in the 10 minute Non-Spinning Reserve markets, the following points must be
provided through the RIG.
Ready to Start—value provided by most peaking units is a combination of the absence of a
trip or lockout, the Generating Unit is not spinning, and the sequence logic is in a ready to
start condition. It is a positive value that allows the CAISO to know the availability of the
peaking unit at any time. If the Ready to Start signal is not positive (high) (1), the CAISO will
interpret this to mean the unit is not available for the 10-minute Non–Spinning Reserve
market. Once the unit start command is issued, Ready to Start should go low and remain
low until the unit is in a mode where it can be started within 10 minutes.
Start-value is used when a start command has been initiated by either manual or automatic
means. It is a positive value that shows the peaking unit is currently in a Start Up mode. If a
purge cycle is required before a start, the Start indication should come on at the start of the
purge cycle. It is maintained until a stop command is issued at which time it becomes a zero
to indicate the peaking unit is currently in shutdown or is offline.
12.3 Non-Spinning Reserve Testing
The test is started by observing the Ready to Start indication is on (High) and unit circuit
breaker is open and Generator KV = 0 and the Start is off (Low). A Start will be requested
and a 10-minute timer will commence. The CAISO expects to see Ready to Start go off
(Low) at this time and Start go on (High). After 10 minutes the POD MW value will be
recorded.
Once the unit is shut down, both start and Ready to Start should be low until the unit is in a
10 minute start mode, then “Ready to Start” is on (HIGH).
If you have any questions about these points or are not sure if they are provided from your
RIG, please contact your CAISO RIG Engineer. The CAISO recommends that the
Generator simulate the Non-Spinning Reserve functionality thoroughly before scheduling the
actual Non-Spinning Reserve test for certification.
For further information and requirements for Ancillary Services, see
http://www.caiso.com/docs/2005/10/05/2005100520285623168.html
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12.4 Proxy Demand Resource Non-Spinning Reserve Testing
PDR Non-Spinning Reserve Testing
The test begins with the PDR Ready to Start indication set to on (High) (1) and the Start
indication set to off (Low) (0). A Start will be requested and a 10-minute timer will
commence. The CAISO expects to see the Ready to Start to set to off (Low) (0) at this time
and the Start and UCON set to on (High) (1).
When the UCON is set to on (High) (1) the Bias Load will hold the current real load value.
The Pseudo Generation will be calculated from the Bias Load and the Real Load. After the
test is over, the Ready to Start is set to on (High) (1) and the Start and UCON is set to off
(Low) (0).
Refer to Section 14 for PDR logic requirements.
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13. Eligible Intermittent Resources (EIR)
13.1 Applicability
Participating Generators with EIRs who wish to enter the Participating Intermittent Resource
program (PIRP) shall comply with all applicable provisions of the CAISO Tariff. The Eligible
Intermittent Resources Protocol (EIRP) in Appendix Q of the CAISO Tariff imposes various
communication and forecasting equipment and forecasting data requirements on EIRs with
PGAs as well as additional requirements on such EIRs electing certification as a
Participating Intermittent Resource (PIR). Section A13 of Appendix A of the BPM for Market
Operations contains additional requirements for EIRs and PIRs that do not pertain to direct
telemetry.
A Generator with an EIR that intends to participate in the CAISO PIRP shall provide
additional meteorological data. The PIRP resources shall have additional data requirements
beyond those applicable to other resources providing direct telemetry due to the importance
of real-time data in developing the hourly forecast for the EIR resource.
13.2 Power Reliability Requirements
The EIR owner must provide a backup power source for the RIG, meteorological station
equipment, revenue meter, and essential communication equipment (not limited to the
router, network switch, fiber optic transceiver, 120V plug-in power supplies, etc.), the backup
power source shall be sized accordingly to carry that equipment load. A backup power
supply may include, but is not limited to, uninterruptable power source (UPS), battery bank
with solar panel charger, or dedicated wind turbine charging a back up battery bank with
inverter. Whichever backup power source is installed, it shall be sized and provide power
until the primary power source is restored.
13.3
Basic Meteorological Data
These are the CAISO required meteorological data points for EIRs participating in PIRP.
13.3.1 Meteorological Wind Speed
The unit of measurement for wind speed will be in meters per seconds (m/s) with a
precision of one m/s.
13.3.2 Meteorological Wind Direction
The unit of measurement for wind direction will be in angular degrees from true north with
a precision of five degrees.
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13.3.3 Meteorological Barometric Pressure
The unit of measurement for barometric pressure will be in Hecto Pascal with a precision
of 60 Hecto Pascal.
13.3.4 Meteorological Ambient Temperature
The unit of measurement for ambient temperature will be in degrees Celsius with a
precision of 1 degree Celsius.
13.4 Wind Generation
13.4.1 Meteorological Station Requirements
Each Generator with a wind EIR must install and maintain equipment required by the
CAISO to support accurate power generation forecasting and the communication of such
forecast, meteorological, and other required data.
A Generator with a wind EIR shall install a minimum of one meteorological tower and two
meteorological stations measuring barometric pressure, temperature, wind speed and
direction, except that the second meteorological station is only required for plants with a
rated capacity of five (5) MW or greater. The meteorological tower should be located on
the windward side of the wind farm. One meteorological station is required to be installed
at the average hub height of the wind turbines. The second meteorological station may be
co-located on the primary meteorological tower and installed approximately 30 meters
below the average hub height.
Where placement of the meteorological station tower(s) in accordance with this
requirement would cause a reduction in production or violation of a local, state, or federal
statute, regulation or ordinance, the CAISO, in coordination with any applicable forecast
service provider, will cooperate with the EIR to identify an acceptable placement of the
meteorological station tower.
The use of SODAR1 and/or LIDAR2 equipment may be an acceptable substitute for wind
direction and velocity based on consultation and agreement with the forecast service
provider and the CAISO.
Hub height is defined as the distance from the ground to the center of the turbine axis.
The station need not actually be located at the hub height, only at a height where
measurements representative of those at the hub height can be taken. The CAISO
recognizes the fact that turbine hub heights are beginning to exceed 80 meters, intruding
into Federal Aviation Administration (FAA) airspace. A meteorological tower exceeding 80
meters incurs additional costs to comply with the FAA lighting requirements. The wind
EIRs will need to work with the forecast service provider to develop the individual
algorithms to calculate the offset of a meteorological tower from the hub height.
1
SODAR – SOnic Detection And Ranging- a meteorological instrument also known as a wind profiler which measures the scattering
of sound waves by atmospheric turbulence.
2
LIDAR – LIght Detection And Ranging - a meteorological instrument which measures the properties of scattered light waves
caused by atmospheric turbulence.
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13.4.2 Designated Turbines
Designated Turbines are required to improve forecast accuracy within a wind park.
Definitions:
Designated Turbine - A turbine designated by the CAISO, in which nacelle wind speed
and generation in MW is required.
Average Horizontal Spacing - The average horizontal distance between a turbine and its
closest neighboring turbine.
Vertical Distance - The elevation difference between the height of a turbine's base and
the height of the base of another turbine.
Designated Turbines shall be selected such that each turbine is within a horizontal
distance of five times Average Horizontal Spacing and a Vertical Distance of 75 meters
of a Designated Turbine and is determined by the CAISO. The Designated Turbine
must be capable of sending the wind speed and power production information to the
CAISO via the RIG.
13.4.3 Topographical Map
A Generator will be required to submit a topographical map that illustrates the location
and height for each wind turbine within the park.
13.5 Solar Generation
13.5.1 Meteorological Station Requirements
Each EIR whose capacity is one MW or greater shall install a minimum of one
meteorological station. Each EIR facility whose capacity is five MW or greater shall
provide a minimum of two meteorological stations. The meteorological data requirements
are set forth in Section 13.4.2.
Solar generating facilities that require direct normal irradiance (DNI) and global horizontal
irradiance (GHI) measurements may provide alternate radiometry meteorological station
data. For example, meteorological station one may report DNI where meteorological
station 2 may report GHI. All other meteorological data reporting requirements shall
remain the same.
Solar generating facilities’ meteorological stations shall cover 90% of the facility’s
footprint for each Resource ID. Each meteorological station shall have a coverage radius
of 7 - 10 miles.
The meteorological station location requirement may be satisfied by a mutually agreeable
sharing arrangement(s) between solar EIRs if:

One such EIR (“Host Plant”) meets the requirement; and

The site of the other EIR (“Sharing Plant”) lies contiguous to or overlaps the site of
the Host Plant, or

Meteorological conditions on its plant site are substantially similar to those on the
Host Plant site.
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Proof of the agreement between the Host Plant and Sharing Plant must be provided to the
CAISO. Should the agreement terminate, the sharing EIR must independently
demonstrate satisfaction of the meteorological tower requirement specified herein.
13.5.2 Meteorological Data Requirements
Table 1 in Section 13.6 represents the minimum required (R) measurement of solar
irradiance by each solar generating technology.
See Section 7 for required data points and Section 17.4 for definitions of the real-time
telemetry data points required for EIRs.
Solar technology definitions

Flat Plate Solar Photovoltaic
Photovoltaic power generation employs solar panels comprising a number of cells
containing a photovoltaic material.


Fixed horizontal / flat roof: The panels are mounted parallel to the sky and the
roof top.
 Fixed angle: The panel is statically fixed to an angle that optimizes its exposure
to the sun year around.
 Azimuth tracking: A panel is attached to a device that tracks the horizontal
movement of the sun to optimize solar production.
 DNI: Direct Normal Irradiance (DNI) is a measure of the solar irradiation striking
a surface held normal to line of sight to the sun.
 Solar zenith angle: Zenith angle is the angle from the zenith (point directly
overhead) to the sun's position in the sky. The zenith angle is dependent upon
latitude, solar declination angle, and time of day.
Flat Panel Solar Collector
A typical flat-plate collector is a metal box with a glass or plastic cover (called
glazing) on top and a dark-colored absorber plate on the bottom. The sides and
bottom of the collector are usually insulated to minimize heat loss. Sunlight passes
through the glazing and strikes the absorber plate, which heats up, changing solar
energy into heat energy. The heat is transferred to liquid passing through pipes
attached to the absorber plate.

Low Concentration Solar Photovoltaic
Low concentration solar photovoltaic is a system that has a solar concentration of 2100 magnification of the suns. This is normally performed with the use of mirror or
other material or devices that concentrate the suns irradiance.

High Concentration Solar Photovoltaic
High concentration solar photovoltaic is a system that has a solar concentration of
300 magnification of the suns or greater. This is normally performed with the use of
mirror or other material or devices that concentrate the suns irradiance.
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
Concentrated Solar Thermal
Concentrated solar thermal systems use lenses or mirrors and tracking systems to
focus a large area of sunlight onto a small area. The concentrated light is then used
as heat or as a heat source for a conventional power plant such as a steam turbine.

Heliostat Power
Heliostat power plants or power towers are a type of solar furnace using a tower to
receive the focused sunlight. They use an array of flat, movable mirrors called
heliostats to focus the sun's rays upon a collector tower.

Greenhouse Power Tower
The greenhouse power tower combines the chimney effect, the greenhouse effect,
and wind turbines to produce power. Air is heated by sunshine and contained in a
very large greenhouse-like structure around the base of a tall chimney, and the
resulting convection causes air to rise up the updraft tower. This airflow drives
turbines, which produce electricity.

Sterling Engine
Sterling engine use the expansion or hot gasses and contraction of cool gasses to
produce mechanical work. The engine is designed so that the working gas is
generally compressed in the colder portion of the engine and expanded in the hotter
portion resulting in a net conversion of heat into work. The cooler part of the engine
at times has compressors to cool the gases, and the hotter part, uses mirrors to
concentrate the heat from the sun.
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13.6 Solar Meteorological Data Tables
Table1
Direct
Irradiance
(DIRD)
Global
Horizontal
Irradiance
(GHIRD)
Global
Irradiance/
Plane of Array
(PAIRD)
Back Pannel
Temperature
(BPTEMP)
Flat-Plate PV
(fixed / horizontal / flat
roof)
R R Flat-Plat PV (fixed angle /
azimuth
tracking)
R R Flat-Plate PV
(DNI zenith & azimuth
tracking)
R R Flat-Plate PV
(DNI zenith & azimuth
tracking)
R R R R R R R R High Concentrating PV
(HCPV)
R R Concentrated Solar
Thermal (solar through
zenith tracking)
R R R R R R R Flat-Panel Solar
(thermal fixed angle
mounted)
Flat-Panel Thermal
Collector (azimuth
tracking)
Low Concentrating PV
(LCPV)
Heliostat Power
(tracking focusing mirrors)
Greenhouse Power
Tower (hot air convection
turbine)
Stirling Engine
(concentrated solar power
generation)
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Table 2
Element Device(s) Needed Units Accuracy Wind Speed (Meter / Second) Anenometer, wind vane and wind mast m/s ± 1 m/s Wind Direction (Degrees ‐ Zero North 90CW) Anenometer, wind vane and wind mast Degrees ± 5⁰ Air Temperature (Degrees Celsius) Temperature probe & shield for ambiant temp ⁰C ± 1⁰ Barometric Pressure (Hecto Pascals) Barometric Temp HPA ± 60 Pa Back Panel Temperature (Degree C) Temperature probe for back ⁰C panel temprature ± 1⁰ Plane Of Array Irradiance Watts\Meter Sq. Pyranometer or Equivalent W/m² ± 25 W/m² Global Horizontal Irradiance Watts\Meter Sq. Pyranometer or Equivalent W/m² ± 25 W/m² Direct Irradiance Watts\Meter Sq. Pyranometer or Equivalent W/m² ± 25 W/m² Table 2 details the units and accuracy of measurements for telemetry data points to be sent to
the CAISO in real time (i.e., 4 seconds) from solar EIRs, depending on the solar technology.
Refer to Section 17.4 for detailed information.
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14. Proxy Demand Resource (PDR)
Proxy Demand Resources shall follow the direct telemetry standards defined in this BPM.
Refer to Section 6.2.2 for telemetry timing requirements.
14.1 PDR Point Requirements
14.1.1 Real Load MW
Each PDR shall be required to provide real load values. The load is the total real time
load or the power consumed by the resource; it can be a directly measured or
calculated. Load data can be provided directly from a field device, such as a revenue
meter, or indirectly by interfacing to a PDR EMS. It can also be derived by statistical
sampling a resource’s underlying load. This data point used to helps establish a
baseline and calculate the load reduction of a resource when the resource is dispatched.
A method for calculating load is not valid unless approved by a CAISO RIG Engineer.
14.1.2 PDR Unit Connectivity Status (PDR UCON)
The PDR UCON can be manually set by an operator or programmed to change status
based on an ADS Dispatch. The PDR UCON represents the resource is connected to
the grid.
14.1.3 Bias Load
Bias load is a calculated value that stores the initial real load of a resource when the
PDR unit connectivity status (UCON) is initially set to ON (HIGH). The bias load is used
to establish a resource’s baseline load.
14.1.4 PDR Unit Ready to Start and Start Status
The PDR Ready to Start and Start status are required only if a PDR is participating in the
Non-Spinning Reserve market. The Ready to Start status should be set to ON (HIGH) if
the resource has been awarded Non-Spinning Reserve by the market and is available
for dispatches. The Start status should be set to ON (HIGH) when the PDR UCON is
ON (HIGH). Both status points can be linked to the PDR UCON status.
14.1.5 Pseudo Generation MW
PDR will be required to provide a pseudo generation point. The pseudo generation
calculates the real load, bias load, and the PDR UCON points. The pseudo generation
calculation can be performed within a control system, EMS, or RIG.
The pseudo generation point allows the CAISO to model the PDR resources like a
market Generating Unit.
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14.1.6 Status` and Pseudo Generation flow
The following chart is the sequence of the ADS signal when it changes for a
PDR.
1A If ADS Dispatch Signal > Zero 1B If ADS Dispatch Signal = Zero 2A Read to Start status = 0 Start status = 1 PDR UCON = 1 Real Load = Feeder Actual MW Bias Load = Real Load Pseudo Gen = Bias Load ‐ Real Load If ADS dispatch > 0 Then Next Else Goto 1B Wait 60 minutes Pseudo Gen = Bias Load ‐ Real Load Goto 2A Read to Start status = 1 Start status = 0 PDR UCON = 0 Bias Load = 0 Pseudo Gen = 0 Goto 1B (The CAISO ADS dispatches to non-Regulation resources)
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The flow chart of the PDR status` and Pseudo Generation MW is shown on figure 8.
FIGURE 8 Calculations for Pseudo Generation
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15. RIG Aggregator
Refer to Sections 6.9, 6.10 and 6.11 for other direct telemetry requirements.
15.1 Applicability
The RIG Aggregator standards in this Section 15 apply to resource owners who plan to
use a single RIG to provide direct telemetry for multiple resources. To optimize the data
gathering process, resources may use a RIG Aggregator to meet the CAISO’s telemetry
requirements instead of installing a RIG for each facility. The RIG Aggregator must be a
resource owner that can enter into agreements with other resource owners to provide
direct telemetry through its RIG.
As described in more detail in the CAISO Tariff, the CAISO Tariff only requires a
resource with a capacity of ten MW or greater or participating in the Ancillary Services
markets or an Eligible Intermittent Resource to provide direct telemetry.
15.2 RIG Aggregator Responsibility
The RIG Aggregator is responsible for the real-time telemetry data aggregation and is
the main contact for data quality issues, accuracy, and communication.
The RIG Aggregator will be responsible for coordinating required data points
telemetered to the CAISO EMS.
In addition to meeting the requirements of Section 5.8 for its own resources, the RIG
Aggregator has the obligation to maintain direct contact with the CAISO for all other
resources that it is aggregating.
15.3 RIG Aggregator Authorization
The RIG Aggregator shall provide a letter on the RIG Aggregator’s letterhead setting
forth a list of all resources that are being aggregated. The letter shall state that the RIG
Aggregator accepts all responsibilities detailed in this BPM. The RIG Aggregator shall
provide accompanying letters from each resource owner granting authorization to the
RIG Aggregator to telemeter data on their behalf to the CAISO.
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16. CAISO Security Policy
16.1 Referencing CAISO Information Security Documents
The CAISO has information security documents relevant to each project. The following
security documents and links to additional security requirements are incorporated into
this BPM. For further information and reliability requirements please contact the CAISO
Network Security.

Basic Assurance Certification Practice Statement (CPS):
http://www.caiso.com/17b4/17b48a5424230.pdf

The ECN Connectivity Requirements link is:
http://www.caiso.com/177d/177d93982c5c0.html

Network Connectivity Security Requirements and ECN Agreement:
http://www.caiso.com/docs/2001/09/26/2001092611012525611.pdf
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17. Real-time Point Definitions
The resource owner is responsible for correctly providing all required points at the accuracy
herein.
17.1 ANALOG VALUES
17.1.1 Unit Gross Megawatts (Gross MW)
Definition:
This quantity is defined as the resource’s real power output, before subtracting the
auxiliary real power load or step-up transformer real power losses.
Purpose:
Gross MW is used to determine the CAISO Balancing Authority Area's generation
pattern in the network model.
Methods of providing this value:
This value can be provided from instrument devices at the resource site (accurate
transducers), at the Generating Unit terminals/low side of the step-up transformer,
before any generation is intermingled with auxiliary load. It may be calculated from
other measured points as agreed to by the CAISO RIG Engineer (i.e., Net MW plus
Aux MW = Gross MW).
17.1.2 Unit Net Megawatts (Net MW)
Definition:
This quantity is defined as the resource’s real power output measured at the low side
of the step up transformer after the auxiliary transformer if applicable. Or the quantity
available after subtracting the unit auxiliary real power load, but before subtracting
the unit step-up transformer real power losses.
Purpose:
Net MW is used to determine the CAISO Balancing Authority Area's generation
pattern used in the network model.
Methods of providing this value:
This value can be provided from instrument devices at the resource site or it may be
calculated from other measured points as agreed to by the CAISO RIG Engineer
(i.e., Gross MW minus Aux MW = Net MW).
If Gross MW is equal to Net MW then Net MW is not required.
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17.1.3 Unit Point of delivery Megawatts (POD MW)
Definition:
This quantity is defined as the compensated, real-time value of the resource’s real
power output at the point the resource connects to the electric grid to the CAISO
Controlled Grid. It should align with the Point-of-delivery (POD) MW calculated or
measured by the CAISO revenue meters. This value is either the actual or calculated
value of the unit’s output at the point where the Generating Unit connects to the
electric grid into the CAISO Controlled Grid. It must be a real time updated value
and not averaged over time. This value is compensated for losses typically arising
from the difference between the measured point and the delivery point (such as
transformer losses, line losses, etc).
Purpose:
POD MW is used to certify Ancillary Services and represents the Generating Unit’s
real power delivery to the system. It is used to validate Ancillary Services Bids
(scheduled versus actual) and to calculate accurate Operating Reserves. This point
is also used as an input to real time network model used for system reliability
monitoring.
Methods of providing this value:
This value may be obtained by installing instrument devices at the POD. This value
may also be calculated by providing an accurate conversion of existing Net MW
values to point of delivery values within the existing control system or external
system. The value must represent an accuracy of +/-2% of the true value of POD
MW represented in the CAISO revenue meter.
17.1.4 Unit Auxiliary Load Megawatts (Aux MW)
Definition:
Aux MW is defined as the real power load the Generating Unit provides to maintain
its station service power. This point is required where a unit’s maximum auxiliary
load is 1 MW or greater. Aux MW cannot represent other loads between the
Generating Unit and the POD.
Purpose:
The CAISO uses this value to determine the amount of replacement power required
by each Generating Unit based on unit trips, startups, etc. This value is used to
properly model the Generating Unit’s operating condition.
Methods of providing this value:
Aux MW can be provided from instrument devices at the auxiliary transformer. It may
be calculated from other measured points as agreed to by the CAISO RIG Engineer
(i.e., Gross MW minus Net MW = Aux MW).
17.1.5 Gross Reactive Power (Gross Megavar (MVAR))
Definition:
This quantity is defined as the unit’s reactive power output, before subtracting the
unit auxiliary reactive power load or unit step-up transformer reactive power losses.
Purpose:
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Gross MVAR is used to determine the CAISO Balancing Authority Area's MVAR
generation pattern in the network model.
Methods of providing this value:
This value can be provided from instrument devices at the generating site (accurate
transducers), at the Generating Unit terminals/low side of the step-up transformer,
before any generation is intermingled with auxiliary MVAR. It may be calculated from
other measured points as agreed to by the CAISO RIG Engineer (i.e., Net MVAR +
Aux MVAR = Gross MVAR).
17.1.6 Point of delivery Megavars (POD MVAR)
Definition:
This quantity is defined as the compensated, real-time value of the reactive power
(MVAR) at the point the Generating Unit connects to the CAISO Controlled Grid. It
should align with the Point-of-delivery (POD) MVAR calculated or measured by the
CAISO revenue meters. This value is either the actual or calculated value of the
unit’s output at the point where the Generating Unit connects into the CAISO
Controlled Grid. It must be a real time updated value and not averaged over time.
This value is compensated for losses typically arising from the difference between
the measured point and the delivery point (such as transformer losses, line losses,
etc).
Purpose:
POD MVAR is used to establish a generating site’s reactive power delivery to the
system and the impact of the generating site on system voltage. It is used to verify
the generating site’s operation within CAISO Tariff requirements for reactive power,
and is used as an input to real time network model used for system reliability
monitoring.
Methods of providing this value:
This value may be obtained by installing instrument devices at the POD. This value
may also be calculated by providing an accurate conversion of another data point
measured at the same voltage level as the POD. The value must represent an
accuracy of +/-2% of the true value of POD MVAR represented in the CAISO
revenue meter.
17.1.7 Net Reactive Power (Net MVAR)
Definition:
This quantity is defined as the unit’s reactive power output after subtracting the unit
auxiliary reactive power load, but before subtracting the unit step-up transformer
reactive power losses.
Purpose:
Net MVAR is used to determine the CAISO Balancing Authority Area's generation
pattern used in the network model.
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Methods of providing this value:
This value can be provided from instrument devices at the generating site or it may
be calculated from other measured points as agreed to by the CAISO RIG Engineer
(i.e., Gross MVAR minus Aux MVAR = Net MVAR). If Gross MVAR is equal to Net
MVAR then Net MVAR is not required.
17.1.8 Auxiliary Load Reactive Power (Aux MVAR)
Definition:
Aux MVAR is defined as the reactive power load the Generating Unit provides to
maintain station service power. This point is required where a unit’s maximum
auxiliary load is one MW or greater. Aux MVAR cannot represent other loads
between the Generating Unit and the POD.
Purpose:
The CAISO uses this value to determine the amount of replacement MVAR required
by each Generating Unit based on unit trips, startups, etc. This value is used to
properly model the Generating Unit’s operating condition.
Methods of providing this value:
Aux MVAR can be provided from instrument devices at the auxiliary transformer. It
may be calculated from other measured points as agreed to by the CAISO RIG
Engineer (i.e., Gross MVAR minus Net MVAR = Aux MVAR).
17.1.9 Generating Unit Terminal Voltage (KV)
Definition:
This quantity is defined as the terminal voltage of the Generating Unit, before the unit
step-up transformer. It may be phase to phase or a calculated value of phase to
ground multiplied by the square root of three. For a Net Scheduled QF subject to a
QF PGA, this quantity is the voltage at the Point of Demarcation.
Purpose:
The CAISO uses generator terminal voltage to determine each Generating Unit’s
contribution to system voltage support. Terminal voltage is critical to proper network
modeling. This value is useful in identifying voltage control issues, MVAR circulation
problems etc.
Methods of providing this value:
This value can be provided from instrument devices at the Generating Unit terminals
(accurate transducers), or, for a Net Scheduled QF subject to a QF PGA, at the Point
of Demarcation.
17.1.10
Unit Operating High Limit (UOHL) (AGC Units Only)
Definition:
The UOHL represents the maximum physical operating limit of the Generating Unit.
The plant control room operator typically sets this limit to prevent the unit MW output
from exceeding an upper plant operating limitation.
Purpose:
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The CAISO uses this value to set the maximum boundary for AGC calculations and
unit availability at the POD.
Method of providing this value:
The real time UOHL value is typically provided directly from the device that the plant
control room operator uses to manually set the operating limits.
17.1.11
Unit Operating Lower Limit (UOLL) (AGC Units Only)
Definition:
The UOLL represents the minimum physical operating limit of the Generating Unit
that participates in ACG. The plant control room operator typically sets this limit to
prevent the unit MW output from exceeding a lower plant operating limitation.
Purpose:
The CAISO uses this value to set the minimum boundary for AGC calculations and
unit availability at the POD.
Method of providing this value:
The real time UOLL value is typically provided directly from the device that the plant
control room operator uses to manually set the operating limits.
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17.2 Digital Values
17.2.1 Unit Generator Breaker
Definition:
The generator breaker is the breaker that closes when the unit is synchronized to the
grid.
Purpose:
The generator breaker positions are needed to determine unit synchronization
status.
Method of providing this value:
The plant or resource control system can provide the status of the breaker.
The following three digital points are required for resources providing Automatic Generation
Control (AGC).
17.2.2 Unit Connectivity Status (UCON)
Definition:
The UCON status is an indication that a unit is synchronized to the grid.
Purpose:
The UCON value is used as a validity check when counting Operating Reserve
contribution. It provides a check and balance in the FNM and provides an indication
of the number of Generating Units connected to the system.
Method of providing this value:
This value is determined from the actual breaker status points of each Generating
Unit and the pre-determined value of Gross MW or the measurement of voltage is
greater than a small percentage of Terminal Voltage. Consult with the CAISO RIG
Engineer to determine the best solution.
17.2.3 Unit Control Status (UCTL)
Definition:
The UCTL represents a software or hardware switch position that the resource is
controlling remotely or locally. The On (High) indicates when the resource is
available for remote supervisory control. The Off (Low) indicates the resource is
controlled locally.
Purpose:
The purpose of the UCTL is to validate whether the resource is providing remote
control to supervised control operators.
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Method of providing this value:
The resource operator selects the UCTL value through an operator interface display
or physical toggle switches. Whichever method is used to select remote or local
control, the indication will come from the resource control system.
17.2.4 CAISO Unit Authority Switch (UASW)
Definition:
The RIG unit authority logic dictates which entity (the Generator, the CAISO, or other
EMS system) has control over a Generating Unit at any given time. When sharing
control of equipment, it is usually necessary to designate and report who has
supervisory control of a specific Generating Unit at any given moment. This is done
to prevent conflicting commands from being issued to the equipment. Unit authority
switching is the means by which control of specific equipment is passed among the
various control groups. Any logic or operator action that prevents or acts against the
CAISO’s direct control will result in this status changing to Off (Low).
Purpose:
When UASW is On (High) the resource will only be available for CAISO AGC Set
Point and no other.
Method of providing this value:
The UASW may be defined as a hardware or software switch. In either case, the
switch must be available to the resource operator through the plant control system.
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17.2.5 Unit Automatic Generation Control (UAGC)
Definition:
The UAGC is the final indication that the resource is ready for the CAISO to send
AGC Set Points. The AGC resource requires an AGC certification in order to
participate in the CAISO Regulation market.
There is one UAGC digital point for each Resource ID.
Purpose:
This point is used for Settlement purposes to determine that the intended resource
met the scheduled generation expectation. When this point is ON (High), the CAISO
EMS AGC control has authority to send MW Set Points to the RIG.
Method of providing the value:
The UAGC status is a calculation result that is made of digital point operand of AND
points UCON, UCTL and UASW. The Set Point shall move the unit within the timing
parameters outline herein.
17.2.6 Automatic Voltage Regulator (AVR) and Power System Stabilizer (PSS) Status
Definition:
The AVR is used to automatically control Generating Unit terminal voltage. The
status must be represented as ON (in automatic control) or OFF (off-line).
The PSS is the system that works with the AVR to respond to frequency excursions.
The status shall be represented as On (in service) or Off (out of service).
Purpose:
AVR and PSS device status points are required to assess system reliability. The
AVR and PSS status points are required from all Generating Units subject to WECC
requirements. These points are also used in post-event analysis and for system
stability simulations.
Method of providing this value:
These values must represent the ON (high) status from the AVR and PSS devices
and may not come from a calculation or user entered value. Data points for AVR and
PSS status are not required for units that do not have these devices installed.
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17.2.7 Peaking Unit Ready to Start and Start Status`
Definition:
The Ready to Start value is provided by the plant control system and shows absence
of a trip or lockout and that the unit is in a ten minute ready to start condition. A
positive value allows the CAISO to know the availability of the resource at any time.
The Start value is the start command that has been initiated either by manual or
automatic means. The Start value is On (High) when the Generating Unit is currently
in a start up mode. It’s maintained On (High) until a unit stop or shutdown command
is initiated at which time it transitions to Off (Low) to indicate the Generating Unit is
currently shutting down or offline.
Purpose:
These values are used to assess the status of peaking units and are used in
Ancillary Services certification and validation of reserve quantities.
Method of providing this value:
These values are obtained directly from plant or resource control systems (i.e.,
PLCs, etc). Typical control system logic provides both these quantities.
17.3 Switchyard Values
The Generator may own some or all of the equipment associated with the connected
switchyard. All switchyard values shall meet telemetry timing requirements. If the
Generator owns switchyard breakers, it shall provide the status retransmitted through
the RIG.
The QF Participating Generator may own some or all of the equipment associated with
the high voltage switchyard interconnecting the QF to the grid. The telemetry of all
switchyard equipment (e.g., circuit breakers, circuit switchers, motor operated
disconnects, transformers, transmission lines, etc.) directly associated with connecting
the QF to the grid must be communicated through the DPG regardless of the
interconnecting equipment’s ownership. If the switchyard directly connects to the ISO
Controlled Grid and the QF Participating Generator owns the other switchyard
equipment, the real time telemetry of all switchyard equipment must be communicated
through the RIG. Where existing telemetry to the ISO is available for this switchyard
equipment (i.e., provided through the UDC), the ISO will not require the telemetry of this
other switchyard equipment to be provided through the DPG, provided the QF
Participating Generator has arranged and can provide the ISO with evidence of a formal
agreement with the UDC to continue to deliver real time switchyard telemetry values on
behalf of the QF Participating Generator. However, the ISO Field Data Acquisition
Engineer must agree with the specific methods used to provide the real time telemetry.
17.3.1 Switchyard Line and Transformer MW and MVAR Values
Definition:
The MW and MVAR quantities for the switchyard’s transmission lines and
transformers.
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Purpose:
These values allow for proper network state estimation and assessment of network
topology and assist in troubleshooting data quality problems (i.e., sum of flows into
and out of a bus). The MW and MVAR values are essential for modeling system
restoration scenarios.
Method of providing this value:
These values are obtained through devices connecting to the line CTs and PTs.
17.3.2 Switchyard Bus Voltage
Definition:
This value is the voltage at the Generating Unit’s switchyard bus. It may be phase to
phase or a calculated value of phase to ground multiplied by the square root of three.
Purpose:
The switchyard bus voltage is used in determining network state estimation. It
identifies voltage concerns and/or system-imposed limitations on reactive support.
Method of providing this value:
This value is provided from bus PTs.
17.3.3 Switchyard Device Status
Definition:
The breakers, circuit switchers, and/or motor operated disconnects (MOD) status for
each Generating Unit, line, bus, and transformer breakers in the Generating Unit’s
switchyard are required.
Purpose:
These values are used in determining network topology for state estimation. They
are required for system restoration and outage information. In some arrangements,
they may be the basis for forming the UCON status.
Method of providing this value:
These values are direct measurements from switchyard devices and/or device
auxiliary contacts.
17.3.4 Aggregated Units
In certain situations, the CAISO allows aggregation of Generating Units and the
associated telemetry. This is typically done where Generating Units are operated in
an interrelated manner (such as through use of a common watershed, operation in
combined cycle configuration, etc.). In these situations it is important to work with the
CAISO RIG Engineer to determine the required data points. The following provides a
guideline to help determine the necessary and correct data points for Aggregated
Units.
17.3.5 Aggregated Gross MW and MVAR
This is a calculation of the sum of the individual unit Gross MW and Gross MVAR
values. When applicable, Gross MW and MVAR are still required for the individual
Generating Units. Requirements will vary on a case-by-case basis.
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17.3.6 Aggregated Net MW and MVAR
This is a calculation of the sum of the individual unit Net MW and Net MVAR values.
When applicable, Net MW and MVAR are still required for the individual Generating
Units. Requirements will vary on a case-by-case basis.
17.3.7 Aggregated Aux MW and MVAR
This is a calculation of the sum of the individual unit Aux MW and Aux MVAR values.
When applicable, Aux MW and MVAR are still required for the individual Generating
Units. Requirements will vary on a case-by-case basis.
17.3.8 Aggregated Point of delivery MW
Aggregated Point of delivery (POD) MW is a required point and is typically the value
of the MW at the point of interconnection to the CAISO Controlled Grid. In this case,
individual Generating Unit POD MW and MVAR are not required.
17.3.9 Aggregated Point of delivery MVAR
TBD
17.3.10
Aggregated Unit Connectivity (UCON)
Aggregated UCON is calculated from the status of all individual Generating Unit
UCONs. For example, Aggregated UCON = Unit 1 UCON OR Unit 2 UCON.
Individual Generating Unit UCON is based on a determination that at least one of the
individual units’ breakers is closed and that a minimum threshold of unit Terminal
Voltage or Gross MW is exceeded. Coordinate with a CAISO RIG Engineer for
calculation.
17.3.11
Aggregated Peaking Unit Start and Ready to Start
Aggregated Unit Start and Ready to Start status points are required. These points
are calculated for the Aggregated Unit, whenever at least one of the individual units
is in a Ready to Start or Start condition.
17.4 Wind and Solar Point Definitions
The EIR owner shall provide the following applicable real-time data points to the
technology used. Section 13.6 provides a table of the required real-time points for each
type of technology.
17.4.1 Direct Irradiance (DIRD)
Direct irradiance can be measured with a pyranometer or equivalent equipment
which measures solar irradiance in Watts per meter (W/m2). All equipment used to
measure solar irradiance shall have an accuracy of ± 25 (W/m2). Direct solar
irradiance is a measure of the rate of solar energy arriving at the earth's surface from
the sun's direct beam, on a plane perpendicular to the beam, and is usually
measured by a sensor mounted on a solar tracker. The tracker ensures that the
sun's beam is always directed into the instrument's field of view during the day.
17.4.2 Global Horizontal Irradiance (GHIRD)
Global horizontal irradiance can be measured with a pyranometer or equivalent
equipment which measures solar irradiance in Watts per meter (W/m2). All
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equipment used to measure solar irradiance shall have an accuracy of ± 25 (W/m2).
The GHI is the total solar radiation (direct, diffuse, and ground-reflected irradiance)
hitting the horizontal surface of the earth. The sensor shall be mounted on a
meteorological station, set at the global horizontal angle of the earth in reference to
the sun solar radiation.
17.4.3 Global Irradiance / Plane of Array Irradiance (PAIRD)
Plane of array irradiance can be measured with a pyranometer or equivalent
equipment which measures solar irradiance in Watts per meter (W/m2). All
equipment used to measure solar irradiance shall have an accuracy of ± 25 (W/m2).
The sensor shall be mounted on a meteorological station, facing the same angle and
direction as all other solar photovoltaic panels at the site.
17.4.4 Diffused Irradiance
Diffuse irradiance refers to all the solar radiation coming from the sky and other
reflected surfaces except for solar radiation coming directly from the sun and the
circumsolar irradiance within approximately three degrees of the sun.


Diffused Plane of Array Irradiance (DPOA): Diffused plan of array irradiance
sensors follow the same accuracy and mounting requirements as the GPOA
sensors but shall be designed to measure diffused irradiance.
Global Diffused Irradiance (DIFGH): Global diffused irradiance sensors follow
the same accuracy and mounting requirements as the GHI sensors but shall be
designed to measure diffused irradiance.
17.4.5 Back Panel Temperature (BPTEMP)
Back panel temperature is measured in degrees Celsius, with an accuracy of one
degree. The temperature sensor should be mounted behind a solar photovoltaic
panel.
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18.
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Drawing Requirements
The resource owner must provide the CAISO a detailed facility one-line drawing showing
how Generating Units, transformers, and auxiliary transformers are connected, all
breaker and disconnect names, CAISO metering, PT, and CT locations, and how the
facility is interconnected to the grid. These schematics shall be the types that are
released for construction or containing a Professional Engineer stamp and released for
construction. The following data can be supplied via additional drawings or supporting
documentation.
Generating Unit data





MVA rating
Rated power factor at PMax
Nominal terminal voltage
Reactive power capability curve (limits)
Terminal voltage control target/range
Transformer data




MVA ratings (normal and emergency ratings in different seasons)
Nominal voltages for all terminal sides
Impedances (listing voltage base and MVA base where the impedance is
calculated)
LTC data, if applicable
o Max tap and min tap
o Voltage control range
o Tap step size and range
o Normal tap position
Generating Unit interconnection facility (gen-tie) data


Line impedance
MVA ratings (normal and emergency ratings in different seasons)
Breaker data

if the breaker is normal open, it needs to be shown in the diagram
Aux load

MW and MVAR level
Reactive support devices (shunt capacitor/reactor, SVC, synchronous condenser)



Rated nominal voltage
Rated MVAR capacity
Number of banks and size of each bank if it has multiple banks
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Voltage control target/range
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Sub-LAP Resource Names
DESCRIPTION
RESOURCE NAMES
PGCC Central Coast
SUB LAP_PGCC
PGEB East Bay (Bay Area)
SUB LAP_PGEB
PGF1 Fresno
SUB LAP_PGF1
PGFG Geysers
SUB LAP_PGFG
PGHB Humboldt
SUB LAP_PGHB
PGLP Los Padres
SUB LAP_PGLP
PGNB North Bay
SUB LAP_PGNB
PGNC North Coast
SUB LAP_PGNC
PGNV North Valley
SUB LAP_PGNV
PGP2 Peninsula (Bay Area)
SUB LAP_PGP2
PGSA Sacramento Valley
SUB LAP_PGSA
PGSB South Bay (Bay Area)
SUB LAP_PGSB
PGSF San Francisco (Bay Area)
SUB LAP_PGSF
PGSI Sierra
SUB LAP_PGSI
PGSN San Joaquin
SUB LAP_PGSN
PGST Stockton
SUB LAP_PGST
SCE Core (LA BASIN)
SUB LAP_SCEC
SCNO SCE North
SUB LAP_SCEN
SCEW SCE West
SUB LAP_SCEW
SCHD High Desert
SUB LAP_SCHD
SCLD Low Desert
SUB LAP_SCLD
SCNW SCE Northwest
SUB LAP_SCNW
SDG1 San Diego
SUB LAP_SDG1
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