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For Reference Only - Not an official CAISO Document of 51

CAISO Metering & Telemetry Requirements Matrix For Reference Only - Not an official CAISO DocumentMatrix ID Requirement Type Metered Entity Market Product Resource Type CAISO System Generator System Document Section # Requirement

1 Non-Functional Metering - - - - 10.1.2

1 Non-Functional Metering - - - - 10.1.2

2 Business Rule Metering - - - - 10.1.3.1






5 Functional Metering - - - - 10.1.3.2

6 Business Rule Metering - - - - 10.1.5


7 Business Rule Metering - - RMDAPS - 3.1

7 Business Rule Metering - - RMDAPS - 3.1

8 Business Rule Metering - - SQMDS - 3.1

9 Non-Functional Metering - - - - 3.2.3.1

9 Non-Functional Metering - - - - 3.2.3.1


Metering or Telemetry

Scheduling Coordinator Metered Entity

CAISO Fifth Replacement FERC Electric Tariff

The CAISO will maintain a record of all Revenue Quality Meter Data and Settlement Quality Meter Data provided to it, as well as the Settlement Quality Meter Data it produces, for a period of 18 months on site at the CAISO’s facilities

CAISO Metered Entity


The CAISO will maintain a record of all Revenue Quality Meter Data and Settlement Quality Meter Data provided to it, as well as the Settlement Quality Meter Data it produces, for a period of 18 months on site at the CAISO’s facilities



CAISO Metered Entities and Scheduling Coordinators may, when providing Meter Data to the CAISO, net MWh values for Generating Unit output and auxiliary Load equipment electrically connected to that Generating Unit at the same point provided that the Generating Unit is on-line and is producing sufficient output to serve all of that auxiliary Load equipment.



CAISO Metered Entities and Scheduling Coordinators may, when providing Meter Data to the CAISO, net MWh values for Generating Unit output and auxiliary Load equipment electrically connected to that Generating Unit at the same point provided that the Generating Unit is on-line and is producing sufficient output to serve all of that auxiliary Load equipment.



CAISO Metered Entities or Scheduling Coordinators may not net values for Generating Unit output and Load. CAISO Metered Entities or Scheduling Coordinators that serve third party Load connected to a Generating Unit’s auxiliary system must add that third party Load to the Generating Unit’s output.












The CAISO Metered Entity may add that third party Load to the Generating Unit’s output either by means of a hard wire local meter connection between the metering systems of the third party Load and the Generating Unit or by requesting the CAISO to use RMDAPS to perform the addition.



The CAISO has complete authority over all rights of access to (and has authority to deny access to) the CAISO’s RMDAPS and Settlement Quality Meter Data Systems including servers (where used), interface equipment, and software needed to collect the relevant information for Settlement, billing and related purposes.





Business Practice Manual for Metering

Revenue Meter Data Acquisition and Processing System (RMDAPS) acquires Revenue Quality Meter Data which is processed into SQMD (actual) for use in the CAISO’s Settlement and billing process



Revenue Meter Data Acquisition and Processing System (RMDAPS) acquires Revenue Quality Meter Data which is processed into SQMD (actual) for use in the CAISO’s Settlement and billing process



Settlement Quality Meter Data System (SQMDS) acquires Scheduling Coordinators’ Settlement Quality Meter Data (actual, estimated)



All metering is of a revenue class metering accuracy in accordance with the ANSI C12 standards on metering and any other requirements of the relevant UDC or Local Regulatory Authority that apply



All metering is of a revenue class metering accuracy in accordance with the ANSI C12 standards on metering and any other requirements of the relevant UDC or Local Regulatory Authority that apply



A CAISO Metered Entity seeking certification of its Metering Facilities independently engages a CAISO Authorized Inspector to perform inspection of its Metering Facilities and requests the CAISO to perform the certification of its Metering Facilities.

G2

CAISO System * Automated Dispatch System (ADS) * Energy Management System (EMS) * Revenue Meter Data Acquisition and Processing System (RMDAPS) * Scheduling and Logging for ISO of California (SLIC) * Settlement Quality Meter Data System (SQMDS) * Energy Communications Network (ECN)

H2

Generator System * Remote Intelligent Gateway (RIG) * Supervisory Control and Data Acquisition (SCADA)


CAISO Metering & Telemetry Requirements Matrix For Reference Only - Not an official CAISO DocumentMatrix ID Requirement Type Metered Entity Market Product Resource Type CAISO System Generator System Document Section # RequirementMetering or

Telemetry










18 Functional Metering - - RMDAPS - 4.1.2

19 Business Rule Metering - - - - G001-New Meter Installations 6.D.2

20 Functional Metering - - - - G001-New Meter Installations 6.D.3 Where there are multiple meters in the metering circuit, each meter shall have its own test switch.

20 Functional Metering - - - - G001-New Meter Installations 6.D.3 Where there are multiple meters in the metering circuit, each meter shall have its own test switch.

21 Business Rule Metering - - - - G002-Unscheduled Meter Outages 6 ISO Metered Entity identifies a metering outage and contacts MDAS Ops immediately upon discovery

22 Business Rule - Metering - - - - G002-Unscheduled Meter Outages 6

23 Business Rule - Metering - - RMDAPS - 6.C.3



The CAISO Metered Entity provides schematics (both detailed and one line) of the metering installation being considered for CAISO certification. Such drawings must be dated, bear the current drawing revision number and show all wiring, connections and devices in the circuits.



Scheduling Coordinators for Scheduling Coordinator Metered Entities must ensure the metered entities they represent have certified meters or must follow the certification process for CAISO Metered Entities.



Scheduling Coordinators representing Scheduling Coordinator Metered Entities must ensure the meters for their Scheduling Coordinator Metered Entities are certified in accordance with the certification requirements of the appropriate Local Regulatory Authority (LRA).



Scheduling Coordinators are responsible for obtaining any necessary approval of the relevant Local Regulatory Authority to its proposed security and VEE procedures.



If the relevant Local Regulatory Authority has not prescribed any certification criteria for the Metering Facilities of a Scheduling Coordinator Metered Entity, the Scheduling Coordinator representing that Scheduling Coordinator Metered Entity must promptly notify the CAISO in writing that no such criteria have been prescribed. That Scheduling Coordinator is then responsible for ensuring that the Scheduling Coordinator Metered Entities it represents obtain and maintain Certificates of Compliance in respect of all of the Metering Facilities of those Scheduling Coordinator Metered Entities in accordance with this BPM. Scheduling Coordinators must engage a CAISO Authorized Inspector to perform the certification of any Metering Facilities that are certified under this BPM and otherwise follow the requirements of Section 3.2.3 for CAISO Metered Entities.



CAISO Metered Entities and Scheduling Coordinators may, when providing Meter Data to CAISO, net MWh values for Generating Unit output and auxiliary Load equipment electrically connected to that Generating Unit at the same point provided that the Generating Unit is on-line and is producing sufficient output to serve all of that auxiliary Load equipment.



CAISO Metered Entities and Scheduling Coordinators may, when providing Meter Data to CAISO, net MWh values for Generating Unit output and auxiliary Load equipment electrically connected to that Generating Unit at the same point provided that the Generating Unit is on-line and is producing sufficient output to serve all of that auxiliary Load equipment.



CAISO Metered Entities or Scheduling Coordinators must not net values for Generating Unit output and Load. CAISO Metered Entities or Scheduling Coordinators that serve third party Load connected to a Generating Unit’s auxiliary system must add that third party Load to the Generating Unit’s output.



CAISO Metered Entities or Scheduling Coordinators must not net values for Generating Unit output and Load. CAISO Metered Entities or Scheduling Coordinators that serve third party Load connected to a Generating Unit’s auxiliary system must add that third party Load to the Generating Unit’s output.



The CAISO Metered Entity must add that third party Load to the Generating Unit’s output either by means of a hard wire local meter connection between the metering systems of the third party Load and the Generating Unit or by requesting CAISO to use RMDAPS to perform the addition.


The prospective ISO Metered Entity develops a Meter Installation proposal, including diagrams and equipment nameplate descriptions




ISO Metered Entity notifies MDAS Operations that meter power has been restored and they are ready to test communications

G003-Change of Metered Entity Ownership

MDAS Operations will reset the meter passwords. After the final meter read the new owner should make any changes required to allow the proper communication with CAISO MDAS (this may involve AT&T). These changes should include revisions to the access control list in the terminal server to allow proper IP filtering for the new owner

G2


H2




Telemetry

24 Functional - Telemetry Intermittent EMS - 2.1

25 Business Rule - Telemetry - Generator - - 3.2.2.1

26 Functional - Telemetry - EMS - 4

27 Functional - Telemetry Generator - - 4

28 Functional - Telemetry - - EMS RIG 5.1

29 Functional - Telemetry - - ECN - 5.2 A single T1 ECN circuit shall be deemed adequate to meet the CAISO's communication requirement

30 Functional - Telemetry - - ECN - 5.2

31 Functional - Telemetry - - - - 5.2

32 Functional - Telemetry - - ECN RIG 5.4

33 Non-Functional - Telemetry - - - - 5.5 All telemetry data reported via the RIG must be within +/-2% of the true value

34 Business Rule - Telemetry - - - RIG 5.5

35 Non-Functional - Telemetry - - ECN RIG 5.6 The protocol required between the RIG and the CAISO's EMS is DNP 3 with PKI security

36 Functional - - - - - - 5.7

37 Functional - Telemetry - - - - 5.8

38 Functional - Telemetry Intermittent - - 6.1

39 Non-Functional - Telemetry - Generator EMS RIG 6.2.1

40 Non-Functional - Telemetry - Generator EMS SCADA 6.2.1

40 Non-Functional - Telemetry - Generator EMS RIG 6.2.1

41 Non-Functional - Telemetry - - - - 6.2.1

42 Non-Functional - Telemetry - - EMS - 6.2.1



Ancillary Services (AS)

Business Practice Manual for Direct Telemetry

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


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

Automatic Generation Control (AGC)


Generating Units offering Automatic Generation Control (AGC) must be capable of being controlled by the CAISO's EMS



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 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



A 128K ISDN ECN digital dial backup circuit is recommended by the CAISO for primary circuit backup for all RIG classes


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


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



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



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)


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



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


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)


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

G2


H2




Telemetry

45 Non-Functional - Telemetry - - - 6.2.2



48 Business Rule - Telemetry - - - RIG 6.3.1 A single serial connection is only acceptable if approved by a CAISO RIG Engineer

49 Non-Functional - Telemetry - - - - 6.3.1 The plant control system shall have a subordinate DNP 3 protocol driver

50 Functional - Telemetry - - - - 6.3.1 The data that comes from metering shall reside in the plant control system



53 Non-Functional - Telemetry - - - - 6.3.2 The SSL device handles the SSL TCP security as defined by the CAISO

54 Non-Functional - Telemetry - - - - 6.3.2 The plant control system must have a subordinate DNP 3 protocol driver

55 Functional - Metering - - - - 6.3.2 The data that comes from metering shall reside in the plant control system


57 Non-Functional - Telemetry - - EMS RIG 6.3.3 Communication between the RIG and the CAISO's EMS is conducted via DNP 3 protocol

58 Business Rule - Telemetry - - - - 6.3.3

59 Business Rule - Telemetry - - - RIG 6.3.3


61 Non-Functional - - - - - - 6.4

62 Non-Functional - - - - ECN - 6.4

63 Non-Functional - - - - EMS - 6.4

64 Non-Functional - - - - - RIG 6.5

65 Functional - - - - - RIG 6.5 The RIG is required to support polling by class

66 Functional - - - - - RIG 6.5


68 Non-Functional - - - - EMS RIG 6.5


Demand Response


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


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





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)


Communication between the plant control system and the CAISO's EMS is conducted via DNP 3 protocol





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 Procedure; section 16)



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


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


DNP 3 Interface: The plant control system shall communicate with DNP 3 subordinate protocol supporting the objects and variations listed herein


PKI Encryption Interface: This layer will be an implementation of SSL using basic assurance certificates for the CAISO's ECN or the internet


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


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



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


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


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


The CAISO's EMS DNP front-end processors interrogate each RIG with DNP Object 60, Variations 2 for event data polling (class 1 data)

G2


H2




Telemetry




73 Non-Functional - - - - - - 6.7

74 Functional - - - - - RIG 6.8

75 Functional - - - - - - 6.8

76 Functional - - - - - - 6.8

77 Non-Functional - - - Generator ECN RIG 6.9

78 Non-Functional - - - Intermittent - RIG 6.9

78 Non-Functional - - - Aggregator - RIG 6.9

79 Functional - - - Aggregator - RIG 6.10 The RIG shall reside within the Sub-LAP for the resources it is aggregating

80 Business Rule - - - Aggregator - RIG 6.10



83 Non-Functional - - - Aggregator - RIG 6.11

84 Business Rule - Telemetry - - - RIG 7.0

85 Non-Functional - - - - - - 7.1

86 Business Rule - - - - - RIG 8.1



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.


Objects and Variations supported by the RIG device must include, but are not limited to: • Static: Object 1 Variation 2 (Digital)• Event: Object 2 Variation 2 (Digital) Object 32 Variation 2 (Analog) • Time: Object 50 Variation 1 (read and write) Object 30 Variation 2 (Analog) • Control: Object type 41 (analog setpoint) Variation 2


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.


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))


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


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


For Eligible Intermittent Resources and RIG Aggregators, the maximum combined generation for a single RIG (including the ECN circuit and router) is 400 MW



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 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


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


Spreadsheet of telemetry points for various resource types which is too complex to include in this requirements list


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

G2


H2




Telemetry

88 Functional - - - - - - 8.1


90 Business Rule - - - - EMS RIG 8.2

91 Functional - - - - - RIG 8.3.1

92 Business Rule - - - - EMS RIG 8.3.1

93 Business Rule - - - - - RIG 8.3.1



96 Non-Functional - - - - EMS RIG 8.3.1

97 Business Rule - - - - EMS RIG 8.3.2

98 Business Rule - - - - - RIG 8.3.3 The resource owner is responsible for all routine testing and maintenance of the RIGs


100 Non-Functional - - - - SLIC RIG 8.3.3

101 Functional - - - - - RIG 8.3.3

102 Functional - - - - - - 9.3


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


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


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


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


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 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


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



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


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


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)

G2


H2




Telemetry

103 Functional - - - - - - 10.7

104 Functional - - - - - - 10.7

105 Non-Functional - - - - - - 10.7

106 Non-Functional - - - - - - 10.7

107 Functional - - - - - - 10.7

108 Functional - - - - - - 10.7

109 Business Rule - - - - - - 10.8

110 Business Rule - - - - - - 10.9 The resource owner must provide 72 hours lead time for scheduled testing times

111 Functional - Telemetry - EMS RIG 11.1

112 Functional - Telemetry - EMS RIG 11.1

113 Functional - - - - RIG 11.2

114 Non-Functional - - - - RIG 12.2

115 Non-Functional - - - - RIG 12.2


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


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


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


At the scheduled RIG testing date, the following personnel are needed for testing: 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; Integrator responsible for the RIG installation; Revenue meter personnel who can inject test values into the meter to verify real-time 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




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 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

AS - Non-spinning Reserve


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



In order to bid in the 10 minute Non-Spinning Reserve markets, the following points must be provided through the RIG: 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

G2


H2




Telemetry

116 Non-Functional - - - - - - 12.3

117 Non-Functional - - - - - - 12.4

118 Functional - - Intermittent - - 13.1

118 Functional - - - - 13.1

119 Functional - - Intermittent - - 13.1

119 Functional - - - - 13.1


121 Non-Functional - - - - 13.3.1

122 Non-Functional - - - - 13.3.2

123 Non-Functional - - - - 13.3.3

124 Non-Functional - - - - 13.3.4

125 Functional - - - - - 13.4.1

125 Functional - - - - - 13.4.1


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).


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

Partipating Intermittent Resource Program (PIRP)


A Generator with an EIR that intends to participate in the CAISO PIRP shall provide additional meteorological data


Eligible Intermittent Resources (EIR)


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




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



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




CAISO required meteorological data points for EIRs participating in PIRP. The unit of measurement for wind speed will be in meters per seconds (m/s) with a precision of one m/s




CAISO required meteorological data points for EIRs participating in PIRP. The unit of measurement for wind direction will be in angular degrees from true north with a precision of five degrees




CAISO required meteorological data points for EIRs participating in PIRP. The unit of measurement for barometric pressure will be in Hecto Pascal with a precision of 60 Hecto Pascal




CAISO required meteorological data points for EIRs participating in PIRP. The unit of measurement for ambient temperature will be in degrees Celsius with a precision of 1 degree Celsius

Intermittent - Wind


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



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

G2


H2




Telemetry

126 Non-Functional - - - - - 13.4.1

126 Non-Functional - - - - - 13.4.1

127 Business Rule - - - - - 13.4.1

127 Business Rule - - - - - 13.4.1

128 Business Rule - - - - - 13.4.1

129 Functional - - - - - 13.5.1

130 Non-Functional - - - - - 13.5.1

131 Functional - - - - - 13.5.2

132 Functional - - - - - 14.0

133 Functional - - - - - 14.1.1

134 Functional - - - ADS - 14.1.2

135 Functional - - - - - 14.1.3

136 Functional - - - - 14.1.4

137 Functional - - - EMS RIG 14.1.5

Intermittent - Wind


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



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

Intermittent - Wind


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



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

Intermittent - Wind


The use of SODAR and/or LIDAR equipment may be an acceptable substitute for wind direction and velocity based on consultation and agreement with the forecast service provider and the CAISO



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

Intermittent - Solar


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



Table 1 in Section 13.6 represents the minimum required (R) measurement of solar irradiance by each solar generating technology

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



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



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



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




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



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

G2


H2




Telemetry

138 Functional - - - ADS - 14.1.6 chart is the sequence of the ADS signal when it changes for a PDR




142 Functional - - - - - - 17.0 The resource owner is responsible for correctly providing all required points at the accuracy herein

143 Functional - - - - - - 17.1.1

144 Functional - - - - - - 17.1.2

145 Non-Functional - - - - - - 17.1.3

146 Functional - - - - - - 17.1.4

147 Functional - - - - - - 17.1.5




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


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


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



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. 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).


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. 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).


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). 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.


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. 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).


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. 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).

G2


H2




Telemetry

148 Non-Functional - - - - - - 17.1.6

149 Functional - - - - - - 17.1.7

150 Functional - - - - - - 17.1.8

151 Functional - - - - - 17.1.9

152 Functional - - - - - - 17.1.10

153 Functional - - - - - - 17.1.11

154 Functional - - - - - - 17.2.1

155 Functional - - - - - - 17.2.2

156 Functional - - - - - - 17.2.3

157 Functional - - - - - RIG 17.2.4


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). 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.


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. 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.


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. 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).

Qualifying Facility (QF)


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. 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.


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. 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.


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. 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.


The generator breaker is the breaker that closes when the unit is synchronized to the grid. The plant or resource control system can provide the status of the breaker


The UCON status is an indication that a unit is synchronized to the grid. 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


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. 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.


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). 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.

G2


H2




Telemetry

158 Functional - - - - - 17.2.5

159 Functional - - - - - - 17.2.6

160 Functional - - - - - - 17.2.7

161 Functional - - - - - RIG 17.3



164 Functional - - - - - - 17.3.1

165 Functional - - - - - - 17.3.2

166 Functional - - - - - - 17.3.3

167 Functional - - - - - - 17.3.5

168 Functional - - - - - - 17.3.6

169 Functional - - - - - - 17.3.7

170 Functional - - - - - - 17.3.8

171 Functional - - - - - - 17.3.10

172 Functional - - - - - - 17.3.11



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. 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.


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). 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.


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. These values are obtained directly from plant or resource control systems (i.e., PLCs, etc). Typical control system logic provides both these quantities.


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 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


The MW and MVAR quantities for the switchyard's transmission lines and transformers. These values are obtained through devices connecting to the line CTs and PTs.


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. This value is provided from bus PTs.


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. These values are direct measurements from switchyard devices and/or device auxiliary contacts.


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.


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.


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.


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.


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.


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.

G2


H2




Telemetry

173 Non-Functional - - - - - 17.4.1

174 Non-Functional - - - - - 17.4.2

175 Non-Functional - - - - - 17.4.3

176 Non-Functional - - - - - 17.4.4

177 Non-Functional - - - - - 17.4.4

178 Non-Functional - - - - - 17.4.5

179 Business Rule - - - - - - 18.0

180 Business Rule - - - - - 10.1.3.3

181 Business Rule - - - - - 10.1.3.3

182 Business Rule - - - - - 10.1.3.3

183 Business Rule - - - - - 10.1.3.3

184 Business Rule - - - - - 10.1.3.3

185 Business Rule - - - - - 10.1.4

186 Business Rule - - - - - 10.1.4

187 Business Rule - - - - - 10.1.4

187 Business Rule - - - - - 10.1.4



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.



Global horizontal 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 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.



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.



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.



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.


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.



A Generating Unit that is a QF and that qualifies as Regulatory Must-Take Generation is subject to the revenue metering requirements set forth in the Existing QF Contract for the QF and is not subject to the revenue metering requirements of Section 10.



A QF Generating Unit not operating under the terms of an Existing QF Contract is subject to the metering requirements of Section 10 prohibiting the net metering of Generation and Load, except if it is subject to a QF PGA.



A Generating Unit that is a QF and that operates under the terms of a QF PGA is eligible for net metering treatment.



A Participating Generator with a QF PGA may net the value for the Generation produced by each Net Scheduled QF listed in its QF PGA and the value for the Demand of the Self-provided Load that is (i) served by the Net Scheduled QF and (ii) electrically located on the same side of the Point of Demarcation.



The Participating Generator with a QF PGA may satisfy the provisions of Section 10 for the installation of revenue metering by installing Metering Facilities at the Point of Demarcation; provided that the installed Metering Facilities satisfy the technical, functional, and performance requirements for Metering Facilities set forth in Section 10 and the applicable Business Practice Manual.



A CAISO Metered Entity shall enter into a Meter Service Agreement for CAISO Metered Entities with theCAISO.



A Scheduling Coordinator representing a Scheduling Coordinator Metered Entity shall enter intoa Meter Service Agreement for Scheduling Coordinators.



If a CAISO Metered Entity is also a Scheduling Coordinator, it shall be treated as a CAISO Metered Entity



If a CAISO Metered Entity is also a Scheduling Coordinator, it shall be treated as a CAISO Metered Entity

G2


H2




Telemetry

188 Business Rule - - - - - 10.1.4

188 Business Rule - - - - - 10.1.4

189 Business Rule - - - RMDAPS - 10.1.5


190 Business Rule - - - - - 10.1.5

191 Business Rule - - - - - 10.1.5

192 Business Rule - - - - - - 10.1.5

193 Business Rule - - - RMDAPS - 10.2

194 Business Rule - - - RMDAPS - 10.2

195 Business Rule - - - RMDAPS - 10.2.1.1

196 Business Rule - - - - - 10.2.1.2

197 Business Rule - - - - - 10.2.1.2

198 Business Rule - - - - - 10.2.1.3



A CAISO Metered Entity will not be required to enter into a Meter Service Agreement for Scheduling Coordinators unless it represents any Scheduling Coordinator Metered Entities. A Meter Service Agreement for Scheduling Coordinators entered into by a CAISO Metered Entity shall only apply to those Scheduling Coordinator Metered Entities that the CAISO Metered Entity represents; the Meter Service Agreement for Scheduling Coordinators shall not apply to the CAISO Metered Entity other than in its capacity as Scheduling Coordinator for those Scheduling Coordinator Metered Entities.



A CAISO Metered Entity will not be required to enter into a Meter Service Agreement for Scheduling Coordinators unless it represents any Scheduling Coordinator Metered Entities. A Meter Service Agreement for Scheduling Coordinators entered into by a CAISO Metered Entity shall only apply to those Scheduling Coordinator Metered Entities that the CAISO Metered Entity represents; the Meter Service Agreement for Scheduling Coordinators shall not apply to the CAISO Metered Entity other than in its capacity as Scheduling Coordinator for those Scheduling Coordinator Metered Entities.









Meter Data supplied by a CAISO Metered Entity shall be made available by the CAISO to the Scheduling Coordinator representing such CAISO Metered Entity at the time the Meter Data was provided and the other authorized users identified in its Meter Service Agreement for CAISO Metered Entities, but shall not be disclosed to any other third party except as may otherwise be required by law, FERC, any Local Regulatory Authority or other provision of this CAISO Tariff.



Meter Data supplied by a Scheduling Coordinator for a Scheduling Coordinator Metered Entity shall be made available by the CAISO to the Scheduling Coordinator representing such Scheduling Coordinator Metered Entity at the time the Meter Data was provided and the other authorized users identified in its Meter Service Agreement for Scheduling Coordinators, but shall not be disclosed to any other third party except as may otherwise be required by law, FERC, any Local Regulatory Authority or other provision of this CAISO Tariff.


Access by third parties other than authorized users to Meter Data held by the CAISO shall be coordinated through the Scheduling Coordinator that provided the Meter Data or that is representing the relevant CAISO Metered Entity that supplied the data and shall not be obtained directly from the CAISO on any basis including, without limitation, by accessing the RMDAPS.



CAISO Metered Entities’ revenue quality meters will be directly polled by the CAISO’s RMDAPS as specified in this CAISO Tariff and Business Practice Manuals.



CAISO Metered Entities shall ensure that Revenue Quality Meter Data from their meters directly connected to the CAISO Controlled Grid or at interconnections thereto, including interconnections between utility Service Areas which have separate UFE calculations, is made available to the CAISO RMDAPS in accordance with the requirements of this Section 10 and the Business Practice Manuals.



CAISO Metered Entities shall ensure that Revenue Quality Meter Data from their meters directly connected to the CAISO Controlled Grid or at interconnections thereto, including interconnections between utility Service Areas which have separate UFE calculations, is made available to the CAISO RMDAPS in accordance with the requirements of this Section 10 and the Business Practice Manuals.



CAISO Metered Entities must ensure that the Meter Data obtained by the CAISO directly from their revenue quality meters is raw, unedited and unaggregated Meter Data in kWh and kVarh values, as specified in the applicable Business Practice Manual.



The CAISO will be responsible for the Validation, Estimation and Editing of that Meter Data in order to produce Settlement Quality Meter Data.



Scheduling Coordinators may obtain Settlement Quality Meter Data relating to the CAISO Metered Entities they represent by directly accessing the Settlement Quality Meter Data Systems as specified in the applicable Business Practice Manual.

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Telemetry

199 Business Rule - - - - - 10.2.1.3

200 Business Rule - - - - - 10.2.1.3

201 Business Rule - - - - - 10.2.1.3

202 Business Rule - - - - - 10.2.2

203 Business Rule - - - - - 10.2.2

204 Business Rule - - - - - 10.2.2

205 Business Rule - - - - - 10.2.3

206 Business Rule - - - - - 10.2.4

207 Business Rule - - - - - 10.2.4

208 Business Rule - - - - - 10.2.4.1

209 Business Rule - - - - - 10.2.4.1

210 Business Rule - - - - - 10.2.4.2

211 Business Rule - - - - - 10.2.4.3

212 Business Rule - - - - - 10.2.4.4



For CAISO Metered Entities, Revenue Quality Meter Data obtained by successfully polled meters will be validated, estimated and edited by the CAISO to produce Settlement Quality Meter Data (actual), which will be made available to Scheduling Coordinators within five (5) Business Days from the Trading Day (T+5B) and will be used in the Recalculation Settlement Statement T+12B calculation.



In the event that Revenue Quality Meter Data remains unavailable at midnight on the eighth (8) Business Day after the Trading Day (T+8B) due to unsuccessfully polled meters or facility and/or systems failures, the CAISO will estimate Settlement Quality Meter Data for CAISO Metered Entities for any outstanding metered Demand and/or Generation for the Recalculation Settlement Statement T+12B calculation as provided in Section 11.1.5.



If the CAISO is notified in accordance with Section 10.2.13.2 that the revenue quality meter for a CAISO Metered Entity requires repair, the CAISO will produce Settlement Quality Meter Data (actual) for that entity using the estimation procedures referred to in Section 10.2.9, which will be made available to the Scheduling Coordinator for the CAISO Metered Entity within forty-eight (48) Business Days from the Trading Day (T+48B) and will be used in the Recalculation Settlement Statement T+55B calculation.



CAISO Metered Entities, at their cost, shall install and maintain, or cause to be installed and maintained, metering equipment and associated communication devices at CAISO-designated Meter Points to meet the requirements of this Section 10 and the applicable Business Practice Manuals.



The CAISO may require CAISO Metered Entities to install, at the cost of CAISO Metered Entities, additional meters and relevant metering system components, including Real-Time metering, at CAISO-specified Meter Points or other locations as deemed necessary by the CAISO, in addition to those connected to or existing on the CAISO Controlled Grid at the CAISO Operations Date.



Nothing in this Section 10 shall preclude CAISO Metered Entities from installing additional meters, instrument transformers and associated communications facilities not deemed necessary by the CAISO at their own cost. A CAISO Metered Entity may not commence installing such additional Metering Facilities until the CAISO has approved the CAISO Metered Entity’s Proposal for Installation.



Each CAISO Metered Entity shall ensure that each of its meters used to provide Meter Data to the CAISO complies with the meter standards and accuracy requirements for meters set forth in this CAISO Tariff and the applicable Business Practice Manuals.



Each CAISO Metered Entity that makes Meter Data available to the CAISO shall ensure that Metering Facilities used to produce such Meter Data have been certified by the CAISO as meeting the requirements of Section 10.



Certification of the relevant Metering Facilities shall only be provided upon the production of such evidence as the CAISO may reasonably require to demonstrate that the facilities in question have been documented, inspected and successfully tested by the CAISO or a CAISO Authorized Inspector for conformance to the standards and accuracy requirements referred to in the Business Practice Manuals and this Section 10.



A CAISO Metered Entity seeking certification of its Metering Facilities shall independently engage a CAISO Authorized Inspector to perform certification of its Metering Facilities.



A CAISO Metered Entity may request the CAISO to perform the certification of its Metering Facilities if it would be impractical or impossible for that CAISO Metered Entity to engage a CAISO Authorized Inspector to perform the certification. The CAISO may refuse any such request by a CAISO Metered Entity if it is of the opinion that it is not impractical or impossible for that CAISO Metered Entity to engage a CAISO Authorized Inspector.



All requests made to the CAISO to perform the certification of Metering Facilities must be made in accordance with the certification process for Metering Facilities and technical specifications published in the Business Practice Manuals and be accompanied by the documents referred to in the applicable Business Practice Manual.



Subject to any exemption granted by the CAISO, the criteria for certifying the Metering Facilities of CAISO Metered Entities pursuant to the CAISO Tariff are the criteria set forth in the Business Practice Manuals.



If the Metering Facilities satisfy the certification criteria as specified in this CAISO Tariff and in the Business Practice Manuals (after taking into account any exemptions to the certification criteria granted by the CAISO), the CAISO will issue a Certificate of Compliance in respect of those Metering Facilities and provide the original Certificate of Compliance to the CAISO Metered Entity that requested the certification of those Metering Facilities.

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213 Business Rule - - - - - 10.2.4.5

214 Business Rule - - - - - 10.2.4.6

215 Business Rule - - - - - 10.2.4.6

216 Business Rule - - - - - 10.2.4.6

217 Business Rule - - - - - 10.2.4.7

218 Functional - - - - - 10.2.6

219 Functional - - - RMDAPS - 10.2.6




223 Business Rule - - - RMDAPS - 10.2.6 The CAISO shall maintain the RMDAPS and remedy any faults occurring in such system.



226 Functional - - - - - 10.2.8

227 Business Rule - - - - - 10.2.8.1

228 Business Rule - - - - - 10.2.8.2.1

229 Business Rule - - - - - 10.2.8.2.1



CAISO Metered Entities must ensure that their Metering Facilities continue to comply with the certificationcriteria referred to in the CAISO Tariff and the Business Practice Manuals.



The CAISO may revoke in full or in part any Certificate of Compliance if: (a) it has reasonable grounds to believe that all or some of the Metering Facilities covered by that Certificate of Compliance no longer meet the certification criteria for Metering Facilities contained in the CAISO Tariff and the Business Practice Manuals; and (b) it has given written notice to the relevant CAISO Metered Entity stating that it does not believe that the identified Metering Facilities meet the certification criteria (including the reasons for that belief) and that CAISO Metered Entity fails to satisfy the CAISO, within the time period specified in the CAISO's notice, that the Metering Facilities meet the certification criteria.



If the CAISO revokes in full or part a Certificate of Compliance, the relevant CAISO Metered Entity may seek recertification of the relevant Metering Facilities by requesting certification. Such request must indicate that it relates to Metering Facilities in respect of which the CAISO has previously revoked a Certificate of Compliance.



Subject to any exemption granted by the CAISO under this CAISO Tariff, the CAISO will not accept Revenue Quality Meter Data from a CAISO Metered Entity unless that Revenue Quality Meter Data is produced by Metering Facilities that are certified in accordance with this CAISO Tariff and the CAISO Metered Entity has a current Certificate of Compliance.



The CAISO’s approval must be obtained before any modifications or changes are made to any Metering Facilities of a CAISO Metered Entity which have been certified pursuant to the CAISO Tariff. The CAISO may, at its discretion, require those Metering Facilities to be recertified.



The CAISO’s RMDAPS shall collect and process Revenue Quality Meter Data made available by CAISO Metered Entities pursuant to Meter Service Agreements for CAISO Metered Entities and the applicabe Business Practice Manual.



Revenue Quality Meter Data for CAISO Metered Entities shall be made available to the CAISO’s RMDAPS as specified in the applicable Business Practice Manual either directly by the CAISO Metered Entity or via a central data server which collects Revenue Quality Meter Data for various CAISO Metered Entities provided that the central data server does not aggregate or adjust that data.



Revenue Quality Meter Data on the CAISO’s RMDAPS may be provided or made accessible to other CAISO systems as deemed necessary by the CAISO, subject to the CAISO being satisfied that such access by such authorized uses and/or systems will not adversely effect the security of the data held by the CAISO.



CAISO Metered Entities shall ensure that their Metering Facilities are compatible with the CAISO’s RMDAPS



The CAISO may, at its discretion, exempt a CAISO Metered Entity from the requirement to make Revenue Quality Meter Data directly available to the CAISO’s RMDAPS, for example, where the installation of communication links is unnecessary, impracticable or uneconomic.





CAISO Metered Entities shall make available to the CAISO's RMDAPS Revenue Quality Meter Data meeting the requirements of this Section 10.



The format of Meter Data to be submitted shall be identified by Transmission Owner, Distribution System, PNode, CAISO Controlled Grid interface point and other information reasonably required by the CAISO.



The CAISO shall correct or replace or cause to be corrected or replaced inaccurate or missing data. The procedure may include data correction and substitution algorithms which shall estimate, substitute and flag such inaccurate or missing data. Any necessary correction or replacement shall be approved by the CAISO prior to the data being sent to the CAISO for Settlement purposes.



Metering Facilities of CAISO Metered Entities (including communications devices) and secondary devices that could have any impact on the performance of the Metering Facilities must be sealed by the CAISO.



If a CAISO Metered Entity desires to grant a third party local access to its revenue quality meters, those meters must be equipped with CAISO approved communications capabilities in accordance with the applicable Business Practice Manuals.



The CAISO may set the password and any other security requirements for locally accessing the revenue quality meters of CAISO Metered Entities so as to ensure the security of those meters and their Revenue Quality Meter Data.

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Telemetry

230 Business Rule - - - - - 10.2.8.2.1

231 Business Rule - - - - - 10.2.8.2.1

232 Business Rule - - - - - 10.2.8.2.1

233 Business Rule - - - - - 10.2.8.2.1

234 Business Rule - - - - - 10.2.8.2.2

235 Business Rule - - - - - 10.2.8.2.2

236 Business Rule - - - - - 10.2.8.2.2

237 Business Rule - - - - - 10.2.8.2.2

238 Business Rule - - - - - 10.2.8.2.2

239 Business Rule - - - - - 10.2.8.2.3

240 Business Rule - - - - - 10.2.8.2.4 The CAISO will provide any needed information to entities that are permitted to access SQMDS.

241 Business Rule - - - - - 10.2.8.2.4

242 Functional - - - - - 10.2.9

243 Business Rule - - - - - 10.2.9.1

244 Non-Functional - - - - - 10.2.9.1 Such assistance shall be rendered in a timely manner so that the Settlement process is not delayed.

245 Non-Functional - - - - - 10.2.9.2

246 Functional - - - - - 10.2.9.2

252 Functional - - - - - 10.2.10.1

253 Business Rule - - - - - 10.2.10.1



The CAISO may alter the password and other requirements for locally accessing those meters from time to time as it determines necessary.



The CAISO must provide CAISO Metered Entities with the current password and other requirements for locally accessing their revenue quality meters.



CAISO Metered Entities must not give a third party other than its Scheduling Coordinator local access to its revenue quality meters or disclose to that third party the password to its revenue quality meters without the CAISO's prior approval as set forth in a schedule to the Meter Service Agreement for CAISO Metered Entities which shall not unreasonably be withheld.



CAISO Metered Entities will be responsible for ensuring that a third party approved by the CAISO to access its revenue quality meters only accesses the data it is approved to access and that the data are only accessed for the purposes for which the access was approved.



The CAISO may set the password and any other security requirements for remotely accessing the revenue quality meters of CAISO Metered Entities so as to ensure the security of those meters and their Revenue Quality Meter Data.



The CAISO will alter the password and other requirements for remotely accessing those meters from time to time as it determines necessary.



The CAISO must provide CAISO Metered Entities with the current password and other requirements for remotely accessing their revenue quality meters.



CAISO Metered Entities must not give a third party other than its Scheduling Coordinator remote access to its revenue quality meters or disclose to that third party the password to its revenue quality meters without the CAISO's prior approval as set forth in a schedule to the Meter Service Agreement for CAISO Metered Entities which shall not unreasonably be withheld.



CAISO Metered Entities will be responsible for ensuring that a third party approved by the CAISO to access its revenue quality meters only accesses the data it is approved to access and that the data are only accessed for the purposes for which the access was approved.



If, in the reasonable opinion of the CAISO, access granted to a third party by a CAISO Metered Entity in any way interferes or impedes with the CAISO's ability to poll any revenue quality meter, the CAISO may require that CAISO Metered Entity to immediately withdraw any access granted to a third party.





The CAISO must maintain the security and integrity of Revenue Quality Meter Data brought into SQMDS.



Subject to any exemption granted by the CAISO, Revenue Quality Meter Data that CAISO MeteredEntities provide to the CAISO will be processed using the Validation, Estimation and Editing procedurespublished in the Business Practice Manuals in order to produce Settlement Quality Meter Data.



At the request of the CAISO, CAISO Metered Entities shall assist the CAISO in correcting or replacing defective data and in detecting and correcting underlying causes for such defects.





Subject to any exemption granted by the CAISO, Meter Data of CAISO Metered Entities must berecorded at 5-minute intervals and will be collected in accordance with the provisions of the applicableBusiness Practice Manual.



The CAISO may also collect Meter Data on demand as provided in the applicable Business Practice Manual.



CAISO Metered Entities may only install revenue quality meters on the low voltage side of step-up transformers if they have obtained the prior approval of the CAISO in accordance with Section 10.2.10.



CAISO Metered Entities that have installed low voltage side metering, whether such installation was before or after the CAISO Operations Date, shall apply the Transformer and Line Loss Correction Factor in accordance with Section 10.2.10.4.

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Telemetry

254 Business Rule - - - - - 10.2.10.2

255 Business Rule - - - - - 10.2.10.4

256 Business Rule - - - RMDAPS - 10.2.10.4

257 Business Rule - - - - - 10.2.11

258 Business Rule - - - - - 10.2.12

259 Business Rule - - - - - 10.2.12

260 Business Rule - - - - - 10.2.12

262 Business Rule - - - - - 10.2.13.1

263 Business Rule - - - - - 10.2.13.2

264 Functional - - - - - 10.2.13.2

266 Functional - - - - - 10.2.14.1

267 Business Rule - - - - - 10.2.14.2

268 Business Rule - - - - - 10.2.14.2

269 Functional - - - - - 10.3

271 Business Rule - - - - - 10.3.2



If a CAISO Metered Entity wishes to install low voltage side metering, it shall submit a written request to the CAISO. That CAISO Metered Entity must: (a) request approval to apply the Transformer and Line Loss Correction Factor to its revenue quality meter or request approval to have the CAISO apply the Transformer and Line Loss Correction Factor; (b) provide detailed reasons to support the request for low side metering; (c) provide all of the information in relation to the Transformer and Line Loss Correction Factor required by the Business Practice Manuals; and (d) any other information reasonably requested by the CAISO.



CAISO Metered Entities will apply the Transformer and Line Loss Correction Factor as set forth in the Business Practice Manuals.



If the CAISO has approved a request from a CAISO Metered Entity for RMDAPS to apply the Transformer and Line Loss Correction Factor, RMDAPS will apply the Transformer and Line Loss Correction Factor set forth in the Business Practice Manuals.



CAISO Metered Entities are subject to CAISO audit, testing and certification requirements for their entire metering system(s), including all relevant communication facilities and instrument transformers.



The CAISO has the authority to grant exemptions from certain CAISO metering standards for a CAISO Metered Entity, as set forth in Section 10.4.



A CAISO Metered Entity with a temporary exemption shall provide site specific Revenue Quality Meter Data to the CAISO in accordance with its Meter Service Agreement for CAISO Metered Entities and the CAISO Tariff.



A Generating Unit that provides Regulatory Must-Take Generation connected directly to a UDC Distribution System and that sells its entire output to the UDC in which the Generating Unit is located is not subject to the audit, testing or certification requirements of the CAISO.



CAISO Metered Entities must maintain their Metering Facilities so that those Metering Facilities continueto meet the standards prescribed by the CAISO Tariff and the applicable Business Practice Manuals.



If a revenue quality meter of a CAISO Metered Entity requires repairs to ensure that it operates in accordance with the requirements of the CAISO Tariff and the applicable Business Practice Manuals, the CAISO Metered Entity must immediately notify the CAISO of the need for repairing that meter and must ensure that those repairs are completed in accordance with the applicable Business Practice Manual.



During periods for which no Revenue Quality Meter Data is available from a meter which has a current Certificate of Compliance, the CAISO will create and provide access to Settlement Quality Meter Data for use in the Settlement Statement calculations, as provided in Section 10.2.1.3.



If the CAISO determines that there is a need to install additional Metering Facilities on the CAISO Controlled Grid pursuant to Section 10.2.2, it will notify the relevant CAISO Metered Entity of that need and will process the CAISO Metered Entity’s Proposal for Installation in accordance with the applicable Business Practice Manual.



If a CAISO Metered Entity installs such additional metering, such metering must, unless the CAISO agrees otherwise: (a) be installed and maintained at the CAISO Metered Entity’s cost; (b) be located on the CAISO Metered Entity’s side of any primary meter; and (c) not interfere with the accuracy of any primary meter and, if that primary meter is directly polled by the CAISO, the CAISO’s ability to directly poll that meter.



Any Meter Data produced by any such additional metering may be used by the CAISO for Settlement and billing purposes in the event of the failure, or during tests or repairs of, the primary meter provided that such additional metering has a current Certificate of Compliance, the CAISO Metered Entity gives the CAISO prior verbal notice that such meter will be used and the period for which it will be used and, if the primary meter is directly polled by the CAISO, the additional metering must also be capable of being directly polled by the CAISO.



If a Scheduling Coordinator Metered Entity is also a Scheduling Coordinator, it shall be treated as a Scheduling Coordinator for the purposes of Section 10 and any references to entities that such a Scheduling Coordinator represents shall be deemed to include that Scheduling Coordinator itself.



Scheduling Coordinators shall be responsible for: (i) the collection of Meter Data for the Scheduling Coordinator Metered Entities it represents; (ii) the provision of Settlement Quality Meter Data to the CAISO; and (iii) ensuring that the Settlement Quality Meter Data supplied to the CAISO meets the requirements of Section 10.

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Telemetry

272 Functional - - - - 10.3.2.1

273 Functional - - - - - 10.3.2.2

274 Non-Functional - - - - - 10.3.2.2

275 Functional - - - - - 10.3.2.2

276 Functional - - - - - 10.3.2.3

277 Functional - - - - - 10.3.3

278 Business Rule - - - - - 10.3.3

279 Business Rule - - - - - 10.3.4

280 Functional - - - - - 10.3.5

281 Non-Functional - - - - - 10.3.6

282 Functional - - - - - 10.3.6

283 Non-Functional - - - - - 10.3.6.1

284 Non-Functional - - - - - 10.3.6.2

285 Functional - - - - - 10.3.6.2

286 Functional - - - - - 10.3.6.2.a

287 Functional - - - - - 10.3.6.2.a


Demand Response


Each Scheduling Coordinator for a Demand Response Provider shall aggregate the Settlement Quality Meter Data of the underlying Proxy Demand Resource to the level of the registration configuration of the Proxy Demand Resource in the Demand Response System.



Scheduling Coordinators shall submit Settlement Quality Meter Data to the Settlement Quality Meter Data System for the Scheduling Coordinator Metered Entities they represent using one of the CAISO’s approved Meter Data Exchange Formats.



Subject to any exemption granted by the CAISO, Scheduling Coordinators must ensure that Settlement Quality Meter Data submitted to the CAISO is in intervals of five (5) minutes for Loads and Generators providing Ancillary Services and/or Imbalance Energy, and one (1) hour for other Scheduling Coordinator Metered Entities.



Each Scheduling Coordinator shall submit Settlement Quality Meter Data in kWh values for all of the Scheduling Coordinator Metered Entities that it schedules aggregated by:(a) LAPs and PNodes, as applicable; and(b) the relevant PNode for Generating Units.



Scheduling Coordinators may obtain Settlement Quality Meter Data relating to the Scheduling Coordinator Metered Entities they represent by requesting extracts from the CAISO’s Settlement Quality Meter Data Systems using the Meter Data request formats as published in the Business Practice Manuals.



Where a Scheduling Coordinator Metered Entity is connected to a UDC’s Distribution System, theresponsible Scheduling Coordinator shall adjust the Meter Data by an estimated Distribution System lossfactor to derive an equivalent CAISO Controlled Grid level measure.



Such estimated Distribution System loss factors shall be approved by the relevant Local Regulatory Authority prior to their use.



Scheduling Coordinators shall be responsible for obtaining all necessary authorizations of Approved Load Profiles from Local Regulatory Authorities having jurisdiction over the use of profiled Meter Data and shall use Approved Load Profiles in any Settlement process in which Load profiles are used to allocate consumption to Settlement Periods.



Each Scheduling Coordinator shall submit Settlement Quality Meter Data for Scheduling Coordinator Metered Entities to the CAISO in accordance with Section 11.29.24.1, Section 37.5, and applicable Business Practice Manuals.



Scheduling Coordinators shall submit to the CAISO Actual Settlement Quality Meter Data or Scheduling Coordinator Estimated Settlement Quality Meter Data, as provided in Section 10.3.6.2(a), for Scheduling Coordinator Metered Entities they represent for each Settlement Period in an Operating Day according to the timelines established in Section 10.3.6.2 and the CAISO Payments Calendar and as provided in the applicable Business Practice Manual.



Scheduling Coordinators must also submit Settlement Quality Meter Data (actual and Scheduling Coordinator estimated) on demand as provided in the applicable Business Practice Manual.



Because Initial Settlement Statement T+3B is solely based on CAISO Estimated settlement Quality Meter Data for metered Demand and Generation, Scheduling Coordinators cannot submit Actual Settlement Quality Meter Data or Scheduling Coordinator Estimated Settlement Quality Meter Data for the entities they represent for purposes of the Initial Settlement Statement T+3B calculation.



Scheduling Coordinators must submit Actual Settlement Quality Meter Data or Scheduling Coordinator Estimated Settlement Quality Meter Data for the Scheduling Coordinator Metered Entities they represent to the CAISO no later than midnight on the eighth (8) Business Day after the Trading Day (T+8B) for the Recalculation Settlement Statement T+12B calculation.



Scheduling Coordinators can submit Estimated Settlement Quality Meter Data for Demand Response Resources.



In the absence of Actual Settlement Quality Meter Data, Scheduling Coordinators may submit Scheduling Coordinator Estimated Settlement Quality Meter Data using interval metering when available, sound estimation practices, and other available information including, but not limited to, bids, schedules, forecasts, temperature data, operating logs, recorders, and historical data.



Scheduling Coordinator Estimated Settlement Quality Meter Data must be a good faith estimate that reasonably represents Demand and/or Generation quantities for each Settlement Period.

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Telemetry

288 Functional - - - - - 10.3.6.2.b

289 Non-Functional - - - - - 10.3.6.3

290 Non-Functional - - - - - 10.3.6.3

291 Non-Functional - - - - - 10.3.6.3.a

292 Non-Functional - - - - - 10.3.6.3.b

293 Non-Functional - - - - - 10.3.6.3.b

294 Business Rule - - - - - 10.3.6.3.c

295 Functional - - - - - 10.3.6.3.c

296 Business Rule - - - - - 10.3.6.3.c

297 Non-Functional - - - - - 10.3.6.3.c

298 Non-Functional - - - - - 10.3.6.4

299 Non-Functional - - - - - 10.3.6.4

300 Non-Functional - - - - - 10.3.6.4

301 Functional - - - - - 10.3.7



When Actual Settlement Quality Meter Data or Scheduling Coordinator Estimated Settlement Quality Meter Data is not received by the CAISO for a Scheduling Coordinator Metered Entity within eight (8) Business Days from the Trading Day (T+8B), the CAISO will estimate the entity’s Settlement Quality Meter Data for any outstanding metered Demand and/or Generation, including Demand Response Resources, for use in the Recalculation Settlement Statement T+12B calculation, as provided in Section 11.1.5.



Scheduling Coordinators must submit Actual Settlement Quality Meter Data for the Scheduling Coordinator Metered Entities they represent to the CAISO no later than midnight on the forty-eighth (48) Business Day after the Trading Day (T+48B) for the Recalculation Settlement Statement T+55B calculation.



A Scheduling Coordinator that timely submits Actual Settlement Quality Meter Data for the Recalculation Settlement Statement T+12B pursuant to Section 10.3.6.2 may submit revised Actual Settlement Quality Meter Data for the Recalculation Settlement Statement T+55B no later than the fortyeighth (48) Business Day after the Trading Day pursuant to this Section.



When Actual Settlement Quality Meter Data is not received by the CAISO for a Scheduling Coordinator Metered Entity by forty-eight (48) Business Days after the Trading Day (T+48B), the Scheduling Coordinator has failed to submit complete and accurate meter data as required by Section 37.5.2.1 and will be subject to monetary penalty pursuant to Section 37.5.2.2.



Any Scheduling Coordinator Estimated Settlement Quality Meter Data submitted by a Scheduling Coordinator on behalf of the Scheduling Coordinator Metered Entities it represents that is not replaced with Actual Settlement Quality Meter Data by forty-eight (48) Business Days after the Trading Day (T+48B) has failed to submit complete and accurate meter data as required by Section 37.5.2.1 and will be subject to monetary penalty pursuant to Section 37.5.2.2.



In the absence of Actual Settlement Quality Meter Data, Scheduling Coordinator Estimated Settlement Quality Meter Data will be used in the Recalculation Settlement Statements.



The CAISO will not estimate a Scheduling Coordinator Metered Entity’s Settlement Quality Meter Data for any outstanding metered Demand and/or Generation for use in a Recalculation Settlement Statement T+55B calculation.



Any previous CAISO Estimated Settlement Quality Meter Data that the Scheduling Coordinator does not replace with Actual Settlement Quality Meter Data by forty-eight (48) Business Days after the Trading Day (T+48B) will be set to zero.



The CAISO will follow the control process described in the BPM for Metering to monitor and identify the CAISO Estimated Settlement Quality Meter Data that was not timely replaced and will take proactive measures to obtain the Actual Settlement Quality Meter Data.



A Scheduling Coordinator that fails to replace CAISO Estimated Settlement Quality Meter Data with Actual Settlement Quality Meter Data by forty-eight (48) Business Days after the Trading Day (T+48B) has failed to provide complete and accurate Settlement Quality Meter Data as required by Section 37.5.2.1 and will be subject to monetary penalty pursuant to Section 37.5.2.2.



Scheduling Coordinators may submit Actual Settlement Quality Meter Data for the Scheduling Coordinator Metered Entities they represent to the CAISO, during the period from one-hundred and sixtyeight Business Days after the Trading Day (T+168B) to one-hundred and seventy-two Business Days after the Trading Day (T+172B) for use in Recalculation Settlement Statement T+9M.



Scheduling Coordinators submitting Actual Settlement Quality Meter Data during the period, from T+168B to T+172B, which is more than forty-eight (48) Business Days after the Trading Day (T+48B) have failed to provide complete and accurate Settlement Quality Meter Data as required by Section 37.5.2.1 and will be subject to monetary penalty pursuant to Section 37.5.2.2.



Any Actual Settlement Quality Meter Data that is submitted by a Scheduling Coordinator after the T+48B meter data submittal deadline, and outside of the period from T+168B to T+172B, will be rejected by the CAISO and not used in settlement calculations.



Each Scheduling Coordinator, in conjunction with the relevant Local Regulatory Authority, shall ensure that each of its Scheduling Coordinator Metered Entities connected to and served from the Distribution System of a UDC shall be metered by a revenue meter complying with any standards of the relevant Local Regulatory Authority or, if no such standards have been set by that Local Regulatory Authority, the metering standards set forth in this CAISO Tariff and as further detailed in the Business Practice Manuals.

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Telemetry

302 Business Rule - - - - - 10.3.8

303 Business Rule - - - - - 10.3.8

304 Business Rule - - - - - 10.3.8

305 Functional - - - - - 10.3.9

306 Functional - - - - - 10.3.9

307 Business Rule - - - - - 10.3.9

308 Business Rule - - - - - 10.3.9

309 Functional - - - - - 10.3.10.1

310 Functional - - - - - 10.3.10.1

311 Business Rule - - - - - 10.3.10.2

312 Business Rule - - - - - 10.3.10.2

313 Business Rule - - - - - 10.3.11

314 Functional - - - - - 10.3.11

315 Functional - - - - - 10.3.11

316 Non-Functional - - - - - 10.3.11.1

317 Functional - - - - - 10.3.14



The CAISO has complete authority over rights of access to (and has authority to deny access to) its Settlement Quality Meter Data Systems by Scheduling Coordinators and Scheduling Coordinator Metered Entities for Settlement, billing and related purposes.



Each Scheduling Coordinator, on behalf of itself and Scheduling Coordinator Metered Entities that it serves or represents, acknowledges this CAISO authority as a condition of access to the CAISO Controlled Grid.



Meter Data of a Scheduling Coordinator Metered Entity remains the property of that Scheduling Coordinator Metered Entity and shall be made available to third parties only with its express permission or the permission of its Scheduling Coordinator or as otherwise required by law or provided for in this CAISO Tariff.



Scheduling Coordinators shall ensure that revenue meters and related Metering Facilities of those Scheduling Coordinator Metered Entities whom they represent are certified in accordance with any certification criteria prescribed by the relevant Local Regulatory Authority or, if no such criteria have been prescribed by that Local Regulatory Authority, certified in accordance with this Section 10.



Scheduling Coordinators shall upon request of the CAISO supply promptly copies of all certificates issued by the relevant Local Regulatory Authority.



Once certified, meters for Scheduling Coordinator Metered Entities need not be recertified provided such meters are maintained so as to meet the standards and accuracy requirements prescribed by any relevant Local Regulatory Authority or, if no such standards have been prescribed by that Local Regulatory Authority, such requirements as referred to in the Business PracticeManuals and this Section 10.



Recertification is not required by the CAISO upon an election by a Scheduling Coordinator Metered Entity to change its Scheduling Coordinator from which it takes service.



Each Scheduling Coordinator shall at least annually conduct (or engage an independent, qualified entity to conduct) audits and tests of the Metering Facilities of the Scheduling Coordinator Metered Entities that it represents and the Meter Data provided to the Scheduling Coordinator in order to ensure compliancewith all applicable requirements of any relevant Local Regulatory Authority.



Scheduling Coordinators shall undertake any other actions that are reasonable necessary to ensure the accuracy and integrity of the Settlement Quality Meter Data (actual or Scheduling Coordinator estimated) provided by them to theCAISO.



Subject to any applicable Local Regulatory Authority requirements, the Metering Facilities and data handling and processing procedures of Scheduling Coordinators and Scheduling Coordinator Metered Entities are subject to audit and testing by the CAISO or a CAISO Authorized Inspector.



Subject to any applicable Local Regulatory Authority requirements, the CAISO will have the right to either conduct any audit or test it considers necessary or to witness such audit or test carried out by the Scheduling Coordinator, Scheduling Coordinator Metered Entity or a CAISO Authorized Inspector engaged by the Scheduling Coordinator, Scheduling Coordinator Metered Entity or the CAISO to carry out those audits or tests.



If the relevant Local Regulatory Authority has not prescribed any certification criteria for the Metering Facilities of a Scheduling Coordinator Metered Entity, the Scheduling Coordinator representing that Scheduling Coordinator Metered Entity must promptly notify the CAISO in writing that no such criteria have been prescribed.



That Scheduling Coordinator will then be responsible for ensuring that the Scheduling Coordinator Metered Entities it represents obtain and maintain Certificates of Compliance in respect of all of the Metering Facilities of those Scheduling Coordinator Metered Entities in accordance with Section 10.3.9.



Scheduling Coordinators must engage a CAISO Authorized Inspector to perform the certification of any Metering Facilities that are to be certified under the CAISO Tariff.



On the written request of the CAISO, each Scheduling Coordinator must give the CAISO written confirmation that the Metering Facilities of each Scheduling Coordinator Metered Entity that it represents are certified in accordance with either the criteria of the relevant Local Regulatory Authority or the criteria prescribed by the CAISO Tariff and Business Practice Manuals within five (5) Business Days of receiving a request from the CAISO.



Scheduling Coordinators shall be responsible for obtaining any necessary approval of the relevant Local Regulatory Authority to its proposed security, validation, editing and estimation procedures.

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318 Business Rule - - - - - 10.3.14

319 Functional - - - - - 10.3.14.1

320 Functional - - - - - 10.3.14.1

321 Non-Functional - - - - - 10.3.17

322 Functional - - - - - 10.3.17

323 Functional - - - - - 10.3.17

324 Non-Functional - - - - - 10.3.17

325 Business Rule - - - - - - 10.4.1

326 Functional - - - - - - 10.4.2

327 Non-Functional - - - - - - 10.4.2

328 Functional - - - - - - 10.4.2

329 Functional - - - - - - 10.4.2

330 Business Rule - - - - - - 10.4.3

331 Functional - - - - - - 10.4.3 The CAISO may require the applicant to provide additional information in support of its application.

332 Non-Functional - - - - - - 10.4.3

333 Non-Functional - - - - - - 10.4.3



The CAISO will not perform any Validation, Estimation and Editing on the Settlement Quality Meter Data it receives from Scheduling Coordinators.



Each Scheduling Coordinator shall be responsible for obtaining any necessary consent from the UDCs on whose Distribution Systems or the Participating TOs on whose transmission facilities the Scheduling Coordinator has Scheduling Coordinator Metered Entities as is necessary to give effect to the procedures governing Meter Data validation and security and inspection and testing of Metering Facilities.



Scheduling Coordinators must verify with the relevant UDC and/or Participating TO the identity of each Scheduling Coordinator Metered Entity they represent and must notify the UDC and/or Participating TO of any discrepancies of which they become aware.



If a Scheduling Coordinator Metered Entity is required to identify its revenue quality meters by the relevant:(a) Local Regulatory Authority; or(b) UDC,then the Scheduling Coordinator representing that Scheduling Coordinator Metered Entity must, at the CAISO's request, provide the CAISO with a copy of that information within five (5) Business Days of a request by the CAISO in a format to be prescribed by the CAISO.



If a Scheduling Coordinator Metered Entity is not required by either the relevant Local Regulatory Authority or UDC to identify its revenue quality meters, the Scheduling Coordinator representing that Scheduling Coordinator Metered Entity shall maintain an accurate record of the revenue quality meter of each of the Scheduling Coordinator Metered Entities that it represents from time to time.



The record maintained by Scheduling Coordinators must include the information set out in the applicable Business Practice Manuals.



The Scheduling Coordinator must, at the CAISO’s request, provide the CAISO with a copy of any information contained in that record within five (5) Business Days of a request by the CAISO in a format to be prescribed by the CAISO.


In addition to the specific exemptions granted under the CAISO Tariff, the CAISO has the authority under the CAISO Tariff to grant exemptions from compliance with certain requirements imposed by the CAISO Tariff.


(a) Publication of GuidelinesThe CAISO will publish on the CAISO Website the general guidelines that it may use when considering applications for exemptions so as to achieve consistency in its reasoning and decision making and to give prospective applicants an indication of whether an application will be considered favorably.


(b) Publication of Exemption ApplicationsThe CAISO will promptly publish on the CAISO Website a description of each application it receives for an exemption.


(c) Publication of DecisionThe CAISO will publish on the CAISO Website details of whether the application was approved or rejected by it and, if the CAISO considers it appropriate, the reasons for rejecting the application.


(d) Class ExemptionsIn addition to exemptions granted to individual entities, the CAISO may grant exemptions that will apply to a class of entities. The CAISO may grant class exemptions whether or not it has received any application for an exemption. The CAISO will publish details of the class exemptions it has granted on the CAISOWebsite.


All applications to the CAISO for exemptions from compliance with the requirements of Section 10 must be made in writing and will be processed by the CAISO in accordance with the provisions of the applicable Business Practice Manual.



The applicant must provide such additional information to the CAISO within five (5) Business Days of receiving the request for additional information or within such other period as the CAISO may notify to the applicant.


If the CAISO makes a request for additional information more than five (5) Business Days after the date on which it received the application, the CAISO will have an additional five (5) Business Days after receiving that additional information in which to consider the application.

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334 Business Rule - - - - - - 10.4.3

335 Functional - - - - RMDAPS - 10.4.4.1

336 Functional - - - - - - 10.4.4.1

337 Functional - - - - - - 10.4.4.2

457 Business Rule - - - - - RIG 2.8 The ISO spreadsheet format is to be used to submit point data for all parties

458 Business Rule - - - - - RIG 2.8 The Generator prepares an engineering proposal for submission to the ISO for approval



461 Business Rule - - - - - RIG 2.16 After the series of tests and tuning that occurs in the testing phase, certification of the RIG is required

462 Business Rule - - - - RIG 2.16 Units that are new to the AGC market will require certification as soon as testing is complete

463 Business Rule - - - RIG 2.16

464 Business Rule - - - - RIG 2.16

465 Business Rule - - - - RIG 2.16

466 Business Rule - - - - ECN RIG RIG/DPG Validation Procedure 2.1.1

467 Functional - - - - - RIG RIG/DPG Validation Procedure 2.1.2

468 Non-Functional - - - - - RIG RIG/DPG Validation Procedure 2.1.2 The diagram should be submitted no later than two weeks prior to testing469 Non-Functional - - - - - RIG RIG/DPG Validation Procedure 2.1.4

470 Non-Functional - - - - RIG RIG/DPG Validation Procedure 2.1.5 To be certified for AGC use, a RIG shall be capable of accepting at least 2 analog outputs

471 Functional - - - - ECN RIG RIG/DPG Validation Procedure 3.0

472 Functional - - - - - RIG RIG/DPG Validation Procedure 3.0 Owners must provide CAISO with the IP address of the circuit473 Non-Functional - - - - - RIG RIG/DPG Validation Procedure 3.0

474 Non-Functional - - - - - RIG RIG/DPG Validation Procedure 3.1 The RIG/DPG must be able to reply with 15 bit plus sign data475 Non-Functional - - - - - RIG RIG/DPG Validation Procedure 3.1 Analog inputs shall have the option to be configured either 0 to 32767 or -32767 to 32767476 Non-Functional - - - - - RIG RIG/DPG Validation Procedure 3.1 All analog inputs are expected to respond accurately and update within 4 seconds477 Functional - - - - - RIG RIG/DPG Validation Procedure 3.1.1 The RIG/DPG must be able to generate an internal heartbeat478 Non-Functional - - - - - RIG RIG/DPG Validation Procedure 3.1.1 The heartbeat must increment one count per second, from 1 to 100 in a continuous loop479 Functional - - - - - RIG RIG/DPG Validation Procedure 3.1.2 For testing the Owner must manually enter each analog input point manually480 Non-Functional - - - - - RIG RIG/DPG Validation Procedure 3.1.2

481 Non-Functional - - - - - RIG RIG/DPG Validation Procedure 3.1.3 The maximum deadband must not exceed 2 counts


If the applicant does not provide the additional information requested, the CAISO may refuse the application in which case it will notify the applicant that its application has been rejected for failure to provide the additional information.


The CAISO has the authority under Section 10.2.6 to exempt CAISO Metered Entities from the requirement to make Meter Data directly available to the CAISO via RMDAPS. The applicable Business Practice Manual sets forth specific exemptions available.


In addition, the CAISO may, at its discretion, grant such an exemption where it considers the requirement to install communication links (or related facilities) between the CAISO Metered Entity and CAISO’s secure communication system to allow the CAISO to directly poll the meters of that CAISO Metered Entity would be unnecessary, impractical or uneconomic.


The CAISO has the authority under Section 10.2.12 to exempt CAISO Metered Entities from the requirement to comply with the meter standards referred to in the CAISO Tariff. The applicable Business Practice Manual sets forth specific exemptions available.

RIG Engineering and Deployment Guide



The ISO Project Engineer will coordinate routing the engineering proposal through the ISO for review and any communication necessary between the ISO, Vendor and Generator to resolve issues with either the database or the engineering design in the proposal


Vendor will finalize the RIG specific mapping in the database and route the database with this mapping to the ISO and the Generator







Units providing AGC through the IOU’s will be required to re-certify in order to continue participation in the ISO ancillary market



Upon completion of the RIG development and production testing, a test for Ancillary Services re-Certification (scheduled through ISO Client Relations and Outage Coordination) must be conducted within 2 weeks



If the Unit’s A/S test raises issues (i.e., poor performance, or failure) further tuning and adjustments may be made. Any additional attempts at A/S re-Certification shall be completed within 4 weeks from the production test checkout

If an Owner chooses to test remotely, then they must have the CAISO Network Agreement submitted before connecting to the CAISO ECN and testing their device

The Owner must provide a communication block diagram of the physical RIG/DPG configuration. The Block diagram should indicate all external devices, and how they are connected to the RIG/DPG. Each port must be labeled and identified, indicating the type of device connected

The RIG/DPG must be configured to allow two DNP master addresses (provided by the CAISO) and the RIG/DPG DNP slave device set to address 1


The Owner may choose to perform validation testing remotely, if so, they must order a CAISO Energy Communication Network AT&T circuit

Owners are expected to have all setup procedures, and DNP certifications completed or provide DNP driver exceptions one week before the testing and validations date

Scaling for each analog input will be tested at zero, minimum, mid scale and maximum scale for accuracy

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483 Functional - - - - - RIG RIG/DPG Validation Procedure 3.1.5 Analog inputs must be able to read all values from minimum to full scale484 Non-Functional - - - - - RIG RIG/DPG Validation Procedure 3.1.5 Each data point must have the option to be configured either 0 to 32767 and or +32767485 Functional - - - - - RIG RIG/DPG Validation Procedure 3.1.6




489 Functional - - - - RIG RIG/DPG Validation Procedure 3.1.9

490 Business Rule - - - - - SCADA RIG/DPG Validation Procedure 3.2.1

490 Business Rule - - - - - RIG RIG/DPG Validation Procedure 3.2.1


492 Functional - - - - EMS RIG RIG/DPG Validation Procedure 3.2.2


494 Functional - - - - - RIG RIG/DPG Validation Procedure 3.2.3 Each communication port shall have a digital point Port Alarm that indicates the port status



497 Non-Functional - - - - - RIG RIG/DPG Validation Procedure 3.2.4 The RIG/DPG must be capable of providing a minimum of 10 Digital Input points to CAISO498 Functional - - - - - RIG RIG/DPG Validation Procedure 3.2.5


500 Functional - - - - EMS RIG RIG/DPG Validation Procedure 3.4.1

501 Functional - - - - - - RIG/DPG Validation Procedure 3.4.2 The RIG/DPG will be safely shut down, and restarted to check for reliability502 Non-Functional - - - - EMS RIG RIG/DPG Validation Procedure 3.5.2

503 Non-Functional - - - - - 10.3.2

The RIG/DPG must be able to perform summing of two or more analog input points. Summing should include the adding and/or subtracting of any number of analog inputs

The RIG/DPG shall be able to send CAISO a data quality indication. The RIG/DPG shall provide a DNP ONLINE / OFFLINE quality flag on a per point basis

The use of DNP ONLINE / OFFLINE quality flag is required for all analog points. When communication is lost with any external device the analog data associated with that device should indicate an OFFLINE status. The use of the DNP ONLINE / OFFLINE quality flag shall be set from within the RIG/DPG

When communication fails between the CAISO and the IG/DPG, CAISO will see the RIG/DPG heartbeat stop. When communication is restored between the two systems theheartbeat in the RIG/DPG shall continue to increment. The heartbeat in the RIG/DPG should continue to increment at all times whether the CAISO is connected or not

The RIG/DPG at a minimum must be capable of performing all calculations in section 3. If the RIG/DPG lacks functionality to perform the calculations, the use supplementary devices, such a PLC to perform calculations is acceptable; however, exceptions will be noted


The RIG may have the option to set up a Bumpless transfer method for AGC control, to track SETPOINT when generating units are off AGC control. A calculated SETPOINT will be stored in the RIG continually updating the set point with the current MW value of the generator. When the generator transfers to CAISO AGC control the generator should not “bump” to a different MW output until a new CAISO MW set point is received at the RIG

CAISO will verify that the correct digital events are displayed at the SCADA interface workstation, and generating a binary input event in the DNP traffic when toggled

CAISO will verify that the correct digital events are displayed at the SCADA interface workstation, and generating a binary input event in the DNP traffic when toggled

The RIG/DPG must demonstrate the ability to send CAISO a data quality indication for each point. It shall provide either a DNP ONLINE / OFFLINE quality flag on a per point basis and a digital port alarm for each communication port

The use of DNP ONLINE / OFFLINE quality flag is required. DNP ONLINE / OFFLINE quality flags will be tested by monitoring DNP traffic between the RIG/DPG and the CAISO EMS

The RIG/DPG shall indicate an OFFLINE data quality for all data associated with an external device if communication is lost with that device. A DNP ONLINE / OFFLINE quality flag shall be set from within the RIG/DPG

The Port Alarm shall be set to TRUE when the communications between the external device(s) and the RIG/DPG has failed communicating. When this event occurs the RIG/DPG will set all associated digital and analog point quality flags to OFFLINE status, until the port is communicating correctly with the external device(s). All other digital or analog points not associated with that port will have the quality flags remain in the ONLINE status

When a failed communication port has returned to normal status those associated digital and analog points will have the quality flags set to ONLINE

The RIG/DPG must be able to perform basic logic functions internally. If the RIG/DPG lacks functionality to perform the calculations, the use of supplementary devices, such as a PLC to perform calculations is acceptable; however, this exception will be noted

At a minimum, the RIG/DPG must be able to perform basic logic calculations, such as AND, OR, and basic compare statements or functions. The RIG/DPG shall perform a calculation that requires a digital point and an analog point logically compared to represent a Unit Connected (UCON) status. The calculation shall be a digital point (Unit Breaker) and an analog point (Unit Mega Watts) greater than 1Mega Watt (MW)

The RIG/DPG will have its power supply terminated to simulate power failure. After the power is restored to the RIG/DPG, the RIG/DPG will be checked for restoration of application functionality and its ability to reconnect to the CAISO EMS after power failure

Communication between the EMS test system and the RIG/DPG must be active for 99.7 percent of the time and not have a single communication failure lasting greater then 5 minutes. The RIG/DPG will only be allowed a reasonable number of communication drops during the tracking period



Scheduling Coordinators shall provide the CAISO with Settlement Quality Meter Data for all Scheduling Coordinator Metered Entities served by the Scheduling Coordinator no later than the day specified in Section 10.3.6.

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504 Functional - - - - - 10.3.2.1

505 Business Rule - - - - - Scheduling Coordinator Agreement 1.2

506 Business Rule - Energy - - - Scheduling Coordinator Agreement 2.1.1

506 Business Rule - - - - Scheduling Coordinator Agreement 2.1.1





509 Business Rule - - Generator - - Scheduling Coordinator Agreement 2.1.4

510 Business Rule - - - - - Scheduling Coordinator Agreement 2.1.5

511 Business Rule - - - - - Scheduling Coordinator Agreement 2.1.6


513 Non-Functional - - - - - Scheduling Coordinator Agreement 4.1



Settlement Quality Meter Data for Scheduling Coordinator Metered Entities shall be either (1) an accurate measure of the actual consumption of Energy by each Scheduling Coordinator Metered Entity in each Settlement Period; (2) for Scheduling Coordinator Metered Entities connected to a UDC Distribution System and meeting that Distribution System’s requirement for Load profiling eligibility, a profile of that consumption derived directly from an accurate cumulative measure of the actual consumption of Energy over a known period of time and an allocation of that consumption to Settlement Periods using the applicable Approved Load Profile; or (3) an accurate calculation by the Scheduling Coordinator representing entities operating pursuant to Existing Contracts.


if there is any inconsistency between this (Scheduling Coordinator) Agreement and the CAISO Tariff, the CAISO Tariff will prevail to the extent of the inconsistency;


The Scheduling Coordinator agrees that: The CAISO Tariff governs all aspects of bidding and scheduling of Energy and Ancillary Services on the CAISO Controlled Grid, including (without limitation), the financial and technical criteria for Scheduling Coordinators, bidding, Settlement, information reporting requirements and confidentiality restrictions;



The Scheduling Coordinator agrees that: The CAISO Tariff governs all aspects of bidding and scheduling of Energy and Ancillary Services on the CAISO Controlled Grid, including (without limitation), the financial and technical criteria for Scheduling Coordinators, bidding, Settlement, information reporting requirements and confidentiality restrictions;


The Scheduling Coordinator agrees that: It will abide by, and will perform all of the obligations under the CAISO Tariff placed on Scheduling Coordinators in respect of all matters set forth therein including, without limitation, all matters relating to the bidding and scheduling of Energy and Ancillary Services on the CAISO Controlled Grid, obligations regarding Resource Adequacy Plans and other requirements of Section 40 of the CAISO Tariff applicable to Scheduling Coordinators for affected Load Serving Entities, ongoing obligations in respect of scheduling, Settlement, system security policy and procedures to be developed by the CAISO from time to time, billing and payments, confidentiality and dispute resolution;



The Scheduling Coordinator agrees that: It will abide by, and will perform all of the obligations under the CAISO Tariff placed on Scheduling Coordinators in respect of all matters set forth therein including, without limitation, all matters relating to the bidding and scheduling of Energy and Ancillary Services on the CAISO Controlled Grid, obligations regarding Resource Adequacy Plans and other requirements of Section 40 of the CAISO Tariff applicable to Scheduling Coordinators for affected Load Serving Entities, ongoing obligations in respect of scheduling, Settlement, system security policy and procedures to be developed by the CAISO from time to time, billing and payments, confidentiality and dispute resolution;


The Scheduling Coordinator agrees that: It shall ensure that each UDC, over whose Distribution System Energy or Ancillary Services are to be transmitted in accordance with Bids submitted to the CAISO by the Scheduling Coordinator, enters into a UDC Operating Agreement in accordance with Section 4.4 of the CAISO Tariff;



The Scheduling Coordinator agrees that: It shall ensure that each UDC, over whose Distribution System Energy or Ancillary Services are to be transmitted in accordance with Bids submitted to the CAISO by the Scheduling Coordinator, enters into a UDC Operating Agreement in accordance with Section 4.4 of the CAISO Tariff;


The Scheduling Coordinator agrees that: It shall ensure that each Generator for which it submits Bids enters into a Participating Generator Agreement in accordance with Section 4.6 of the CAISO Tariff;


The Scheduling Coordinator agrees that: It shall have the primary responsibility to the CAISO, as principal, for all Scheduling Coordinator payment obligations under the CAISO Tariff;


The Scheduling Coordinator agrees that: Its status as a Scheduling Coordinator is at all times subject to the CAISO Tariff.


The Scheduling Coordinator shall maintain at all times an account with a bank capable of Fed-Wire transfer to which credits or debits shall be made in accordance with the billing and Settlement provisions of Section 11 of the CAISO Tariff.


Such (settlement) account shall be the account as notified by the Scheduling Coordinator to the CAISO from time to time by giving at least 20 days written notice before the new account becomes operational, together with all information necessary for the CAISO's processing of a change in that account.

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522 Business Rule - - - - - Scheduling Coordinator Agreement 13.1 Such (right assignment/transfer) consent shall not be unreasonably withheld.








The CAISO Tariff is incorporated herein and made a part hereof. In the event of a conflict between the terms and conditions of this Agreement and any other terms and conditions set forth in the CAISO Tariff, the terms and conditions of the CAISO Tariff shall prevail.


All submitted applications, schedules, Bids, confirmations, changes to information on file with the CAISO and other communications conducted via electronic transfer (e.g. direct computer link, FTP file transfer, bulletin board, e-mail, facsimile or any other means established by the CAISO) shall have the same legal rights, responsibilities, obligations and other implications as set forth in the terms and conditions of the CAISO Tariff as if executed in written format.


All submitted applications, schedules, Bids, confirmations, changes to information on file with the CAISO and other communications conducted via electronic transfer (e.g. direct computer link, FTP file transfer, bulletin board, e-mail, facsimile or any other means established by the CAISO) shall have the same legal rights, responsibilities, obligations and other implications as set forth in the terms and conditions of the CAISO Tariff as if executed in written format.


The Scheduling Coordinator shall be responsible for all its costs incurred for the purpose of meeting its obligations under this Agreement.


In the event any dispute is not settled, the Parties shall adhere to the CAISO ADR Procedures set forth in Section 13 of the CAISO Tariff, which is incorporated by reference, except that any reference in Section 13 of the CAISO Tariff to Market Participants shall be read as a reference to the Scheduling Coordinator and references to the CAISO Tariff shall be read as references to this Agreement.


The provisions of Section 14 of the CAISO Tariff will apply to liability arising under this (Scheduling Coordinator) Agreement, except that all references in Section 14 of the CAISO Tariff to Market Participants shall be read as references to the Scheduling Coordinator and references to the CAISO Tariff shall be read as references to this Agreement.


Section 14.1 of the CAISO Tariff shall be incorporated by reference into this (Scheduling Coordinator) Agreement except that all references in Section 14.1 of the CAISO Tariff to Market Participants shall be read as a reference to the Scheduling Coordinator and references to the CAISO Tariff shall be read as references to this Agreement.


Either Party may assign or transfer any or all of its rights and/or obligations under this Agreement with the other Party’s prior written consent in accordance with Section 22.2 of the CAISO Tariff.



Any such transfer or assignment shall be conditioned upon the successor in interest accepting the rights and/or obligations under this Agreement as if said successor in interest was an original Party to this (Scheduling Coordinator) Agreement.


Any notice, demand or request which may be given to or made upon either Party regarding this (Scheduling Coordinator) Agreement shall be made in accordance with Section 22.4 of the CAISO Tariff, provided that all references in Section 22.4 of the CAISO Tariff to Market Participants shall be read as a reference to the Scheduling Coordinator and references to the CAISO Tariff shall be read as references to this Agreement, and unless otherwise stated or agreed shall be made to the representative of the other Party indicated in Schedule 1.


A Party must update the information in Schedule 1 of this (Scheduling Coordinator) Agreement as information changes. Such changes shall not constitute an amendment to this (Scheduling Coordinator) Agreement.


Any waiver at any time by either Party of its rights with respect to any default under this (Scheduling Coordinator) Agreement, or with respect to any other matter arising in connection with this Agreement, shall not constitute or be deemed a waiver with respect to any subsequent default or other matter arising in connection with this Agreement.


Any delay, short of the statutory period of limitations, in asserting or enforcing any right under this (Scheduling Coordinator) Agreement shall not constitute or be deemed a waiver of such right.


This (Scheduling Coordinator) Agreement shall be deemed to be a contract made under, and for all purposes shall be governed by and construed in accordance with, the laws of the State of California, except its conflict of law provisions.

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538 Business Rule - - - - - 1.3

539 Business Rule - - - - - 3.1

540 Business Rule - - - - - 3.1

541 Functional - - - SQMDS - 3.2.1


542 Non-Functional - - - SQMDS - 3.2.1

542 Non-Functional - - - RMDAPS - 3.2.1

543 Functional - - - - - 3.2.2


The Parties irrevocably consent that any legal action or proceeding arising under or relating to this Agreement to which the CAISO ADR Procedures do not apply, shall be brought in any of the following forums, as appropriate: any court of the State of California, any federal court of the United States of America located in the State of California, or, where subject to its jurisdiction, before the Federal Energy Regulatory Commission.


This (Scheduling Coordinator) Agreement shall incorporate by reference Section 22.9 of the CAISO Tariff as if the references to the CAISO Tariff were referring to this Agreement.


This (Scheduling Coordinator) Agreement constitutes the complete and final agreement of the Parties with respect to the subject matter hereof and supersedes all prior agreements, whether written or oral, with respect to such subject matter.


If any term, covenant, or condition of this (Scheduling Coordinator) Agreement or the application or effect of any such term, covenant, or condition is held invalid as to any person, entity, or circumstance, or is determined to be unjust, unreasonable, unlawful, imprudent, or otherwise not in the public interest by any court or government agency of competent jurisdiction, then such term, covenant, or condition shall remain in force and effect to the maximum extent permitted by law, and all other terms, covenants, and conditions of this Agreement and their application shall not be affected thereby, but shall remain in force and effect and the Parties shall be relieved of their obligations only to the extent necessary to eliminate such regulatory or other determination unless a court or governmental agency of competent jurisdiction holds that such provisions are not separable from all other provisions of this Agreement.


This (Scheduling Coordinator) Agreement and the Schedules attached hereto may be amended from time to time by the mutual agreement of the Parties in writing.


Amendments that require FERC approval shall not take effect until FERC has accepted such amendments for filing and made them effective.


Nothing contained herein (in the Scheduling Coordinator Agreement) shall be construed as affecting in any way the right of the CAISO to unilaterally make application to FERC for a change in the rates, terms and conditions of this Agreement under Section 205 of the FPA and pursuant to FERC’s rules and regulations promulgated thereunder, and the Scheduling Coordinator shall have the right to make a unilateral filing with FERC to modify this Agreement pursuant to Section 206 or any other applicable provision of the FPA and FERC’s rules and regulations thereunder; provided that each Party shall have the right to protest any such filing by the other Party and to participate fully in any proceeding before FERC in which such modifications may be considered.


Nothing in this (Scheduling Coordinator) Agreement shall limit the rights of the Parties or of FERC under Sections 205 or 206 of the FPA and FERC’s rules and regulations thereunder, except to the extent that the Parties otherwise mutually agree as provided herein.


This (Scheduling Coordinator) Agreement may be executed in one or more counterparts at different times, each of which shall be regarded as an original and all of which, taken together, shall constitute one and the same Agreement.


Meter Service Agreement for ISO Metered Entities

if there is any inconsistency between this (Meter Service for ISO Entities) Agreement and the CAISO Tariff, the CAISO Tariff will prevail to the extent of the inconsistency;



This (Meter Service for ISO Entities) Agreement shall be subject to the provisions of the CAISO Tariff which shall be deemed to be incorporated herein, as the same may be changed or superseded from time to time.



The Parties agree that they will comply with the provisions of Section 10 and all other applicable provisions of the CAISO Tariff and the applicable Business Practice Manual implementing Section 10 of the CAISO Tariff.



The CAISO Metered Entity agrees to make available to the CAISO through SQMDS and RMDAPS its Meter Data in accordance with the CAISO Tariff.



The CAISO Metered Entity agrees to make available to the CAISO through SQMDS and RMDAPS its Meter Data in accordance with the CAISO Tariff.



The CAISO’s requirements regarding the frequency with which it requires Meter Data to be made available to it through SQMDS and RMDAPS by the CAISO Metered Entity are referred to in the CAISO Tariff.



The CAISO’s requirements regarding the frequency with which it requires Meter Data to be made available to it through SQMDS and RMDAPS by the CAISO Metered Entity are referred to in the CAISO Tariff.



The CAISO Metered Entity shall provide in the format prescribed by Schedule 1 to this (Meter Service for ISO Entities) Agreement the required information with respect to all of its meters used to provide Meter Data to the CAISO.

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544 Business Rule - - - - - 3.2.2

545 Business Rule - - - - - 3.2.2

546 Business Rule - - - - - 3.2.2 Such modification shall be effective upon receipt of notice by the CAISO.

547 Functional - - - - - 3.2.3

548 Business Rule - - - - - 3.2.4

549 Business Rule - - - - - 3.2.4

550 Business Rule - - - - - 3.2.4

551 Non-Functional - - - - - 3.2.5

552 Functional - - - - - 3.3.1

553 Business Rule - - - - - 3.3.2

554 Business Rule - - - - - 3.3.3

555 Business Rule - - - - - 3.3.4

556 Business Rule - - - - - 3.3.4

557 Business Rule - - - - - 4.1

558 Business Rule - - - - - 4.1

559 Business Rule - - - - - 4.1

560 Business Rule - - - - - 4.1

561 Business Rule - - - - - 4.2



The CAISO Metered Entity must immediately notify the CAISO of any changes to the information provided to the CAISO in accordance with this Section 3.2.2 and provide the CAISO with any information in relation to such change as reasonably requested by the CAISO.



The CAISO Metered Entity shall have the right to modify Schedule 1, which modification shall not constitute an amendment to this (Meter Service for ISO Entities) Agreement.





If the CAISO Metered Entity uses low voltage side metering or metering connected to the Distribution System, it shall use the CAISO approved Transformer and Line Loss Correction Factor referred to in the CAISO Tariff and in the applicable Business Practice Manual.



The CAISO Metered Entity shall use its best efforts to procure any rights necessary for the CAISO to access all Metering Facilities of the CAISO Metered Entity to fulfill its obligations under the CAISO Tariff and its obligations under this (Meter Service for ISO Entities) Agreement.



If, after using its best efforts, the CAISO Metered Entity is unable to provide the CAISO with such access rights, the CAISO Metered Entity shall ensure that one of its employees is a CAISO Authorized Inspector and such employee undertakes, at the CAISO’s request, the certification, testing, inspection and/or auditing of those Metering Facilities in accordance with the procedures established pursuant to the CAISO Tariff, including the requirement to complete and provide to the CAISO all necessary documentation.



The CAISO acknowledges that it will not be prevented from fulfilling its obligations under the CAISO Tariff or this Agreement by reason of the fact that it is provided with escorted access to the Metering Facilities of the CAISO Metered Entity.



The security measures and the validation, editing and estimation procedures that the CAISO will apply to Meter Data made available to the CAISO by the CAISO Metered Entity shall be as referred to in the CAISO Tariff.



The CAISO shall allow the Scheduling Coordinator representing the CAISO Metered Entity and all Authorized Users to directly poll CAISO certified meters for the Meter Data relating to the CAISO Metered Entity in accordance with the procedures referred to in the CAISO Tariff and the applicable Business Practice Manual.



The CAISO shall be a third-party beneficiary to any future agreement between the CAISO Metered Entity and any other party relating to the Metering Facilities of the CAISO Metered Entity for the purpose of granting the CAISO access to any relevant information, records and facilities as needed by the CAISO to fulfill its obligations under the CAISO Tariff and its obligations under this Agreement.



The CAISO shall provide the CAISO Metered Entity any password or other requirements necessary for the CAISO Metered Entity to access its Meter Data remotely or locally at the meter.



Any exemptions provided for under the CAISO Tariff that are granted by the CAISO shall be set forth in Schedule 2 of this (Meter Service for ISO Entities) Agreement.



Any amendment or addition to Schedule 2 shall not constitute an amendment to this (Meter Service for ISO Entities) Agreement.



If a CAISO Metered Entity provides inaccurate or incorrect Meter Data or fraudulent Meter Data to the CAISO, the CAISO shall be entitled to impose penalties and sanctions, including but not limited to suspension of trading rights following 14 days written notice to the CAISO Metered Entity. Fraudulent Meter Data means any Meter Data provided to the CAISO by the CAISO Metered Entity that it knows to be false, incorrect or incomplete at the time it provided that Meter Data to the CAISO.



All penalties and sanctions shall be set forth in Schedule 4 Part A to this (Meter Service for ISO Entities) Agreement or in the CAISO Tariff.



No penalties or sanctions, including suspension of trading rights, may be imposed under this (Meter Service for ISO Entities) Agreement unless a Schedule or CAISO Tariff provision providing for such penalties or sanctions has first been filed with and made effective by FERC.



Nothing in the (Meter Service for ISO Entities) Agreement, with the exception of the provisions relating to the CAISO ADR Procedures, shall be construed as waiving the rights of the CAISO Metered Entity to oppose or protest any penalty proposed by the CAISO to the FERC or the specific imposition by the CAISO of any FERC-approved penalty on the CAISO Metered Entity.



If the CAISO Metered Entity fails to meet or maintain the standards for Metering Facilities or comply with the audit or test procedures as referred to in the CAISO Tariff, the CAISO shall be permitted to take corrective measures.

G2


H2




Telemetry

562 Business Rule - - - - - 4.2

563 Business Rule Metering - - SQMDS - 5.1

564 Business Rule - - - - - 5.1

565 Business Rule - - - - - 5.1

566 Business Rule - - - - - 5.1

567 Business Rule - - - - - 6.1

568 Business Rule - - - - - 6.1

569 Business Rule - - - - - 7.1

570 Business Rule - - - - - 7.1

571 Business Rule - - - - - 8.1

572 Business Rule Metering - - - - 8.2

573 Business Rule - - - - - 9.1

574 Business Rule - - - - - 10.1

575 Business Rule - - - - - 11.1

576 Business Rule - - - - - 11.1

577 Business Rule - - - - - 11.2

578 Business Rule - - - - - 11.2



The corrective measures and rights the CAISO may exercise upon any failure by any entity to meet those standards for Metering Facilities or to comply with the audit or test procedures shall be set forth in Schedule 4 Part B (in the Meter Service Agreement for ISO Metered Entities Agreement) or in the CAISO Tariff.



In addition to the persons referred to in the CAISO Tariff, including the CAISO Metered Entity and the relevant Scheduling Coordinator, as being entitled to access Meter Data on SQMDS, the CAISO Metered Entity may set forth in Schedule 3 of this Agreement any additional Authorized Users that shall be entitled to access the CAISO Metered Entity’s Settlement Quality Meter Data held by the CAISO.



The CAISO Metered Entity shall include in Schedule 3 (in the Meter Service Agreement for ISO Metered Entities Agreement) as Authorized Users the relevant UDCs and TOs.



The CAISO shall provide the Authorized Users with any password or other information necessary to access the CAISO Metered Entity’s Settlement Quality Metered Data held by the CAISO on SQMDS.



Any amendment or addition to Schedule 3 (in the Meter Service Agreement for ISO Metered Entities Agreement) shall not constitute an amendment to this Agreement.



The CAISO Metered Entity shall be responsible for all reasonable costs incurred by the CAISO or a CAISO Authorized Inspector in connection with them carrying out the certification, inspection, testing or auditing of the meters identified in Schedule 1 (in the Meter Service Agreement for ISO Metered Entities Agreement) from which the CAISO Metered Entity provides Meter Data to the CAISO.



The CAISO or CAISO Authorized Inspector will furnish the CAISO Metered Entity, upon request, an itemized bill for such (Certification, Inspection and Auditing) costs.



The Parties shall make reasonable efforts to settle all disputes arising out of or in connection with this (Meter Service for ISO Entities) Agreement.



In the event any dispute is not settled, the Parties shall adhere to the CAISO ADR Procedures set forth in Section 13 of the CAISO Tariff, which is incorporated by reference, except that all reference in Section 13 of the CAISO Tariff to Market Participants shall be read as a reference to the CAISO Metered Entities and references to the CAISO Tariff shall be read as references to this (Meter Service for ISO Entities) Agreement.



Each Party represents and warrants that the execution, delivery and performance of this (Meter Service for ISO Entities) Agreement by it has been duly authorized by all necessary corporate and/or governmental actions, to the extent authorized by law.



The CAISO Metered Entity represents that all necessary approvals, permits, licenses, easements, right of way or access to install, own and operate its meters have been or will be obtained by the CAISO Metered Entity prior to the effective date of this (Meter Service for ISO Entities) Agreement.



The provisions of Section 14 of the CAISO Tariff will apply to liability arising under this (Meter Service for ISO Entities) Agreement, except that all references in Section 14 of the CAISO Tariff to Market Participants shall be read as references to the CAISO Metered Entity and references to the CAISO Tariff shall be read as references to this Agreement.



Section 14.1 of the CAISO Tariff shall be incorporated by reference into this Agreement except that all references in Section 14.1 of the CAISO Tariff to Market Participants shall be read as references to the CAISO Metered Entity and all references to the CAISO Tariff shall be read as references to this (Meter Service for ISO Entities) Agreement.



Either Party may assign or transfer any or all of its rights and/or obligations under this (Meter Service for ISO Entities) Agreement with the other Party’s prior written consent in accordance with Section 22.2 of the CAISO Tariff. Such consent shall not be unreasonably withheld.



Any such transfer or assignment shall be conditioned upon the successor in interest accepting the rights and/or obligations under this Agreement as if said successor in interest was an original Party to this (Meter Service for ISO Entities) Agreement.



Any notice, demand or request which may be given to or made upon either Party regarding this Agreement shall be made in accordance with Section 22.4 of the CAISO Tariff, provided that all references in Section 22.4 of the CAISO Tariff to Market Participants shall be read as a reference to the CAISO Metered Entity and references to the CAISO Tariff shall be read as references to this (Meter Service for ISO Entities) Agreement, and unless otherwise stated or agreed shall be made to the representative of the other Party indicated in Schedule 5.



A Party must update the information in Schedule 5 as information changes. Such changes shall not constitute an amendment to this (Meter Service for ISO Entities) Agreement.

G2


H2




Telemetry

579 Business Rule - - - - - 11.3

580 Business Rule - - - - - 11.3

581 Business Rule - - - - - 11.4

582 Business Rule - - - - - 11.4

583 Business Rule - - - - - 11.5

584 Business Rule - - - - - 11.6

585 Business Rule - - - - - 11.7

586 Business Rule - - - - - 11.8

587 Business Rule - - - - - 11.8

588 Business Rule - - - - - 11.8

589 Business Rule - - - - - 11.9

590 Business Rule - - - - - 1.2

591 Business Rule - - - - - 2.2.1



Any waiver at any time by either Party of its rights with respect to any default under this Agreement, or with respect to any other matter arising in connection with this (Meter Service for ISO Entities) Agreement, shall not be deemed a waiver with respect to any subsequent default or other matter arising in connection with this Agreement.



Any waiver at any time by either Party of its rights with respect Any delay short of the statutory period of limitations, in asserting or enforcing any right under this (Meter Service for ISO Entities) Agreement shall not constitute or be deemed a waiver of such right.



This (Meter Service for ISO Entities) Agreement shall be deemed to be a contract made under and for all purposes shall be governed by and construed in accordance with the laws of the State of California, except its conflict of law provisions.



The Parties irrevocably consent that any legal action or proceeding arising under or relating to this (Meter Service for ISO Entities) Agreement to which the CAISO ADR Procedures do not apply shall be brought in any of the following forums, as appropriate: any court of the State of California, any federal court of the United States of America located in the State of California or, where subject to its jurisdiction, before the Federal Energy Regulatory Commission.



This Agreement shall incorporate by reference Section 22.9 of the CAISO Tariff as if the references to the CAISO Tariff were referring to this (Meter Service for ISO Entities) Agreement.



This (Meter Service for ISO Entities) Agreement constitutes the complete and final agreement of the Parties with respect to the subject matter hereof and supersedes all prior agreements, whether written or oral, with respect to such subject matter.



If any term, covenant, or condition of this (Meter Service for ISO Entities) Agreement or the application or effect of any such term, covenant, or condition is held invalid as to any person, entity, or circumstance, or is determined to be unjust, unreasonable, unlawful, imprudent, or otherwise not in the public interest by any court or government agency of competent jurisdiction, then such term, covenant, or condition shall remain in force and effect to the maximum extent permitted by law, and all other terms, covenants, and conditions of this Agreement and their application shall not be affected thereby, but shall remain in force and effect and the parties shall be relieved of their obligations only to the extent necessary to eliminate such regulatory or other determination unless a court or governmental agency of competent jurisdiction holds that such provisions are not separable from all other provisions of this Agreement.



This (Meter Service for ISO Entities) Agreement and the Schedules attached hereto may be amended from time to time by the mutual agreement of the Parties in writing. Amendments that are subject to FERC approval shall not take effect until FERC has accepted such amendments for filing and has made them effective.



Nothing contained herein shall be construed as affecting in any way the right of the CAISO to unilaterally make application to FERC for a change in the rates, terms and conditions of this Agreement under Section 205 of the FPA and pursuant to FERC’s rules and regulations promulgated thereunder, and the CAISO Metered Entity shall have the right to make a unilateral filing with FERC to modify this (Meter Service for ISO Entities) Agreement pursuant to Section 206 or any other applicable provision of the FPA and FERC’s rules and regulations thereunder; provided that each Party shall have the right to protest any such filing by the other Party and to participate fully in any proceeding before FERC in which such modifications may be considered.



Nothing in this (Meter Service for ISO Entities) Agreement shall limit the rights of the Parties or of FERC under Sections 205 or 206 of the FPA and FERC’s rules and regulations thereunder, except to the extent that the Parties otherwise mutually agree as provided herein.



This (Meter Service for ISO Entities) Agreement may be executed in one or more counterparts at different times, each of which shall be regarded as an original and all of which, taken together, shall constitute one and the same Agreement.


Meter Service Agreement for Scheduling Coordinators

if there is any inconsistency between this (Meter Service for Scheduling Coordinators) Agreement and the CAISO Tariff, the CAISO Tariff will prevail to the extent of the inconsistency;



This (Meter Service for Scheduling Coordinators) Agreement shall terminate upon acceptance by FERC of such notice of termination, if filed with FERC, or thirty (30) days after the date of the CAISO’s notice of default, if terminated in accordance with the requirements of FERC Order No. 2001 and related FERC orders.

G2


H2




Telemetry

592 Business Rule - - - - - 3.1

593 Business Rule - - - - - 3.2

594 Business Rule - - - - - 3.2

595 Business Rule - - - - - 3.3.1

596 Business Rule - - - - - 3.3.1

597 Business Rule - - - - - 3.3.1

598 Business Rule - - - - - 3.3.2

599 Business Rule - - - - - 3.3.3

600 Business Rule - - - - - 3.3.3

601 Business Rule - - - - - 3.3.3

602 Business Rule - - - - - 3.3.4.1

603 Business Rule - - - - - 3.3.4.1

604 Business Rule - - - - - 3.3.4.2

605 Business Rule - - - - - 3.3.4.2

606 Business Rule - - - - - 4.1



This (Meter Service for Scheduling Coordinators) Agreement shall be subject to the provisions of the CAISO Tariff which shall be deemed to be incorporated herein, as the same may be changed or superseded from time to time. The Parties agree that they will comply with the provisions of Section 10 and all other applicable provisions of the CAISO Tariff.



The Scheduling Coordinator shall ensure that the Scheduling Coordinator Metered Entities it represents shall adhere to the requirements and standards for Metering Facilities of its Local Regulatory Authority.



If that Scheduling Coordinator Metered Entity’s Local Regulatory Authority has not set any requirements or standards in relation to any of its Metering Facilities, the Scheduling Coordinator representing that Scheduling Coordinator Metered Entity must comply with the requirements and standards for those Metering Facilities as set forth in this Agreement and the CAISO Tariff.



If the CAISO so requests, the Scheduling Coordinator shall provide in the format prescribed by Schedule 1 to this (Meter Service for Scheduling Coordinators) Agreement the required information with respect to the meters for all Scheduling Coordinator Metered Entities it represents including the reference to specific distribution loss factors or methodology it proposes to use as determined by the relevant UDC and approved by the relevant Local Regulatory Authority.



The Scheduling Coordinator must immediately notify the CAISO of any changes to the information provided to the CAISO in accordance with this Section 3.3.1 (in the Meter Service for Scheduling Coordinators Agreement) and provide the CAISO with any information in relation to such change as reasonably requested by the CAISO.



Any amendments or additions to Schedule 1 shall not constitute an amendment to this (Meter Service for Scheduling Coordinators) Agreement.



The Scheduling Coordinator shall ensure that the CAISO shall, upon reasonable notice, have access to the entire Metering Facilities of the Scheduling Coordinator Metered Entities that it represents from the meter data server to the Metering Facilities in order to inspect, test or otherwise audit those Metering Facilities.



The Scheduling Coordinator shall provide the CAISO with any applicable Approved Load Profile for each Scheduling Coordinator Metered Entity that it represents that is load profiled in accordance with the CAISO Tariff.



The Scheduling Coordinator shall provide a copy of the Approved Load Profile applicable to each Scheduling Coordinator Metered Entity (if any) that it represents, which shall be set forth in Schedule 2 to this (Meter Service for Scheduling Coordinators) Agreement.



The Scheduling Coordinator must immediately notify the CAISO of any changes to the Approved Load Profiles referred to in Schedule 2 to this Agreement and provide the CAISO with a copy of the new or amended Approved Load Profile. Such change to Schedule 2 shall not constitute an amendment to this (Meter Service for Scheduling Coordinators) Agreement.



Any exemptions provided for under the CAISO Tariff that are granted by the CAISO shall be set forth in Schedule 3 to this Agreement.



Any amendment or addition to Schedule 3 shall not constitute an amendment to this (Meter Service for Scheduling Coordinators) Agreement.



The CAISO shall be a third-party beneficiary to the agreements between the Scheduling Coordinator and Scheduling Coordinator Metered Entities that the Scheduling Coordinator epresents.



Such agreements (between the Scheduling Coordinator and Scheduling Coordinator Metered Entities) shall grant the CAISO access to any relevant information, records and facilities of the Scheduling Coordinator Metered Entity as needed for the CAISO to fulfill its obligations under this (Meter Service for Scheduling Coordinators) Agreement and the CAISO Tariff.



If the Scheduling Coordinator provides inaccurate or incorrect Settlement Quality Meter Data or fraudulent Meter Data to the CAISO, the CAISO shall be entitled to impose penalties and sanctions, including but not limited to suspension of trading rights following 14 days written notice to the Scheduling Coordinator

G2


H2




Telemetry

607 Business Rule - - - - - 4.1

608 Business Rule - - - - - 4.1

609 Business Rule - - - - - 4.1

610 Business Rule - - - - - 4.1

611 Business Rule - - - - - 4.2

612 Business Rule - - - - - 4.2

613 Business Rule - - - - - 5.1

614 Business Rule - - - - - 5.1

615 Business Rule - - - - - 5.1

616 Business Rule - - - - - 5.1

617 Business Rule - - - - - 5.1

618 Business Rule - - - - - 6.1

619 Business Rule - - - - - 6.1

620 Business Rule - - - - - 7.1

621 Business Rule - - - - - 7.1

622 Business Rule - - - - - 8.1



Fraudulent Meter Data means any data provided to the CAISO by the Scheduling Coordinator that the Scheduling Coordinator knows to be false, incorrect or incomplete at the time it provided it to the CAISO. All penalties and sanctions shall be set forth in Schedule 4 Part A or in the CAISO Tariff. No penalties or sanctions, including the suspension of trading rights, may be imposed under this Agreement unless a Schedule or CAISO Tariff provision providing for such penalties or sanctions has first been filed with and made effective by FERC.



Nothing in the (Meter Service for Scheduling Coordinators) Agreement, with the exception of the provisions relating to the CAISO ADR Procedures, shall be construed as waiving the rights of the Scheduling Coordinator to oppose or protest any penalty proposed by the CAISO to the FERC or the specific imposition by the CAISO of any FERC-approved penalty on the Scheduling Coordinator.



CAISO of any FERC-approved penalty on the Scheduling Coordinator. The CAISO will provide notice to all Scheduling Coordinators of any filing of proposed penalties or sanctions with the FERC.



The CAISO shall notify the Scheduling Coordinator of those approved penalties within 14 days of their approval by the FERC.



If the Scheduling Coordinator or any Scheduling Coordinator Metered Entity that it represents fails to meet or maintain the standards for Metering Facilities or comply with the audit or test procedures as set forth in the CAISO Tariff, the CAISO shall be permitted to take corrective measures.



Details of the corrective measures and rights the CAISO may exercise upon any failure by any entity to meet those standards for Metering Facilities or to comply with the audit or test procedures shall be set forth in Schedule 4 Part B or in the CAISO Tariff.



Third parties that are authorized by the Scheduling Coordinator to access the Meter Data of a Scheduling Coordinator Metered Entity held by the CAISO and that are entitled to such Meter Data shall be identified in Schedule 5 to this (Meter Service for Scheduling Coordinators) Agreement.



The Scheduling Coordinator shall not provide a third party access to Meter Data of a Scheduling Coordinator Metered Entity unless the Scheduling Coordinator has permission from that Scheduling Coordinator Metered Entity to provide that access.



The relevant UDCs and TOs shall be included in Schedule 5 provided that the Scheduling Coordinator Metered Entity has granted those UDCs and TOs access to its Meter Data.



Any amendment or addition to Schedule 5 shall not constitute an amendment to this (Meter Service for Scheduling Coordinators) Agreement.



The Scheduling Coordinator shall, on request by the Scheduling Coordinator Metered Entity, access the Meter Data held by the CAISO relating to that Scheduling Coordinator Metered Entity and provide that Meter Data to the Scheduling Coordinator Metered Entity in a timely manner.



The Scheduling Coordinator shall be responsible for all reasonable costs incurred by the CAISO or a CAISO Authorized Inspector in connection with them carrying out the certification, inspection, testing or auditing of the meters identified in Schedule 1 from which the Scheduling Coordinator provides Meter Data to the CAISO.



The CAISO or CAISO Authorized Inspector will furnish the Scheduling Coordinator, upon request, an itemized bill for such costs.



The Parties shall make reasonable efforts to settle all disputes arising out of or in connection with this (Meter Service for Scheduling Coordinators) Agreement.



In the event any dispute is not settled, the Parties shall adhere to the CAISO ADR Procedures set forth in Section 13 of the CAISO Tariff, which is incorporated by reference, except that all reference in Section 13 of the CAISO Tariff to Market Participants shall be read as a reference to the Scheduling Coordinator Metered Entity and references to the CAISO Tariff shall be read as references to this (Meter Service for Scheduling Coordinators) Agreement.



Each Party represents and warrants that the execution, delivery and performance of this Agreement by it has been duly authorized by all necessary corporate and/or governmental actions, to the extent authorized by law.

G2


H2




Telemetry

623 Business Rule - - - - - 8.2

624 Business Rule - - - - - 8.3

625 Business Rule - - - - - 9.1

626 Business Rule - - - - - 10.1

627 Business Rule - - - - - 11.1

628 Business Rule - - - - - 11.2

629 Business Rule - - - - - 11.2

630 Business Rule - - - - - 11.3

631 Business Rule - - - - - 11.3

632 Business Rule - - - - - 11.3

633 Business Rule - - - - - 11.4

634 Business Rule - - - - - 11.5

635 Business Rule - - - - - 11.5



The Scheduling Coordinator represents and warrants that all of the entities which it identifies on Schedule 1 as Scheduling Coordinator Metered Entities that it represents have granted it all necessary authority to enable it to carry out its obligations under this Agreement and the CAISO Tariff, and, subject to the execution and delivery by the CAISO, this (Meter Service for Scheduling Coordinators) Agreement will be enforceable against the Scheduling Coordinator in accordance with its terms.



The Scheduling Coordinator represents and warrants that all third parties referred to in Schedule 5 to this (Meter Service for Scheduling Coordinators) Agreement have been authorized by the relevant Scheduling Coordinator Metered Entity as having access to its Settlement Quality Meter Data.



The provisions of Section 14 of the CAISO Tariff will apply to liability arising under this Agreement except that all references in Section 14 of the CAISO Tariff to Market Participants shall be read as references to the Scheduling Coordinator and references in the CAISO Tariff shall be read as references to this (Meter Service for Scheduling Coordinators) Agreement.



Section 14.1 of the CAISO Tariff shall be incorporated by reference into this Agreement except that all references in Section 14.1 of the CAISO Tariff to Market Participants shall be read as references to the Scheduling Coordinator and all references to the CAISO Tariff shall be read as references to this (Meter Service for Scheduling Coordinators) Agreement.



Either Party may assign or transfer any or all of its rights and/or obligations under this Agreement with the other Party’s prior written consent in accordance with Section 22.2 of the CAISO Tariff. Such consent shall not be unreasonably withheld. Any such transfer or assignment shall be conditioned upon the successor in interest accepting the rights and/or obligations under this Agreement as if said successor in interest was an original Party to this (Meter Service for Scheduling Coordinators) Agreement.



Any notice, demand or request which may be given to or made upon either Party regarding this Agreement shall be made in accordance with the Scheduling Coordinator’s Scheduling Coordinator Agreement and in accordance with Section 22.4 of the CAISO Tariff, provided that all references in Section 22.4 of the CAISO Tariff to Market Participants shall be read as a reference to the Scheduling Coordinator and references to the CAISO Tariff shall be read as references to this (Meter Service for Scheduling Coordinators) Agreement, and unless otherwise stated or agreed shall be made to the representative of the other Party indicated in Schedule 6.



A Party must update the information in Schedule 6 as information changes. Such changes shall not constitute an amendment to this (Meter Service for Scheduling Coordinators) Agreement.



Any waiver at any time by either Party of its rights with respect to any default under this (Meter Service for Scheduling Coordinators) Agreement, or with respect to any other matter arising in connection with this Agreement, shall not be deemed a waiver with respect to any subsequent default or other matter arising in connection with this Agreement.



Any delay short of the statutory period of limitations in asserting or enforcing any right under this (Meter Service for Scheduling Coordinators) Agreement shall not constitute or be deemed a waiver of such right.



This Agreement shall incorporate by reference Section 22.9 of the CAISO Tariff as if the references to the CAISO Tariff were referring to this Agreement.



This Agreement shall be deemed to be a contract made under and for all purposes shall be governed by and construed in accordance with the laws of the State of California, except its conflict of law provisions.



The Scheduling Coordinator irrevocably consents that any legal action or proceeding arising under or relating to this Agreement to which the CAISO ADR Procedures do not apply shall be brought in any of the following forums, as appropriate: any court of the State of California, any federal court of the United States of America located in the State of California or, where subject to its jurisdiction, before the Federal Energy Regulatory Commission.



This (Meter Service for Scheduling Coordinators) Agreement shall incorporate by reference Section 22.9 of the CAISO Tariff as if the references to the CAISO Tariff were referring to this Agreement.

G2


H2




Telemetry

636 Business Rule - - - - - 11.7

637 Business Rule - - - - - 11.8

638 Business Rule - - - - - 11.8

639 Business Rule - - - - - 11.8

640 Business Rule Metering - Generator - - 4

641 Business Rule - - Generator - - 4


643 Business Rule - - Generator - - 4 Under no circumstances may ineligible loads be served through a Station Power meter.

644 Business Rule - - Generator - - 4 Each Station Power meter must be subject to a Meter Service Agreement for ISO Metered Entities.





648 Business Rule - - Generator - - 6 Station Power should be scheduled, and meter data will be collected by the CAISO.







If any term, covenant, or condition of this (Meter Service for Scheduling Coordinators) Agreement or the application or effect of any such term, covenant, or condition is held invalid as to any person, entity, or circumstance, or is determined to be unjust, unreasonable, unlawful, imprudent, or otherwise not in the public interest by any court or government agency of competent jurisdiction, then such term, covenant, or condition shall remain in force and effect to the maximum extent permitted by law, and all other terms, covenants, and conditions of this Agreement and their application shall not be affected thereby, but shall remain in force and effect and the Parties shall be relieved of their obligations only to the extent necessary to eliminate such regulatory or other determination unless a court or governmental agency of competent jurisdiction holds that such provisions are not separable from all other provisions of this Agreement.



Amendments that are subject to FERC approval shall not take effect until FERC has accepted such amendments for filing and has made them effective.



Nothing contained herein shall be construed as affecting in any way the right of the CAISO to unilaterally make application to FERC for a change in the H544rates, terms and conditions of this Agreement under Section 205 of the FPA and pursuant to FERC’s rules and regulations promulgated thereunder, and the Scheduling Coordinator shall have the right to make a unilateral filing with FERC to modify this (Meter Service for Scheduling Coordinators) Agreement pursuant to Section 206 or any other applicable provision of the FPA and FERC’s rules and regulations thereunder; provided that each Party shall have the right to protest any such filing by the other Party and to participate fully in any proceeding before FERC in which such modifications may be considered.



Nothing in this (Meter Service for Scheduling Coordinators) Agreement shall limit the rights of the Parties or of FERC under Sections 205 or 206 of the FPA and FERC’s rules and regulations thereunder, except to the extent that the Parties otherwise mutually agree as provided herein.


California ISO Station Power Program Overview

The owner-applicant must identify and provide one-line diagrams of all Generating Units and Station Power meters for the “portfolio” over which Station Power is proposed to beself-supplied. Meter location and ownership of facilities should be clearly shown.



Each Station Power meter must be certified in accordance with the ISO Tariff, and all end uses served must meet the definition of Station Power.



All load served by each Station Power meter must be consistent with the definition of Station Power, and any ineligible load must have appropriate retail metering in place. Separate metering is not required if the values of two or more meters can be netted to properly record and reportloads that are ineligible for Station Power service.







Any costs associated with required metering or telemetry are the responsibility of the owner-applicant.



A single Scheduling Coordinator must be assigned to both the On-Site Self-Supply and Remote Self Supply Load IDs associated with each Station Power meter.



A single Scheduling Coordinator must be assigned to both the On-Site Self-Supply and Remote Self Supply Load IDs associated with each Station Power meter.



The CAISO will verify metering schemes and assign Load IDs to the responsible Scheduling Coordinators when a Station Power Portfolio is approved.





The default load ID for each meter is the "On-Site Self-Supply Load ID", which would be assigned to the portfolio owner's SC.



The second Load ID that will be assigned to each Station Power meter is the “Third Party Supply Load ID”, which will be associated with the Scheduling Coordinator of the UDC responsible for retail service.



The second Load ID that will be assigned to each Station Power meter is the “Third Party Supply Load ID”, which will be associated with the Scheduling Coordinator of the UDC responsible for retail service.



If Station Power load exceeds the available Generation, then the ISO will shift a portion of reported load to the Third Party Supply Load ID.

G2


H2




Telemetry





656 Functional Metering - Generator - - 6







663 Business Rule Metering - Generator - - III

664 Business Rule Metering - Generator - - III

665 Business Rule Metering - Generator - - IV

666 Business Rule Metering - Generator - - IV

667 Business Rule Metering - Generator - -






If there are one or more Generating Units in the Station Power Portfolio that could remotely self supply load served by a Station Power meter, then a “Remote Self Supply Load ID” will also be specified for that meter.



The Remote Self-Supply Load ID will facilitate settlement of transmission charges, and will be associated with the portfolio owner’s Scheduling Coordinator.



The portfolio owner’s SC will not be allowed to schedule using the Remote Self Supply Load ID, but will exclusively schedule any Load using the On-Site Self Supply Load ID.



Any load that is not contemporaneously netted with Generation will be associated with the On-Site Load ID, unless some portion is reassigned to another Load ID at the end of the Netting Period.



At the end of the month the CAISO will determine what portion of the metered Station Power load in each Settlement Interval was served by Remote Self-Supply or Third Party Supply, and will reassign load from the On-Site Self-Supply Load ID to the Remote Self-Supply Load ID or Third Party Supply Load ID accordingly.



The ISO will make any reallocation of meter data to the Remote Self-Supply and Third Party Supply Load IDs for each unit by Settlement Interval before the Preliminary Settlement Statement is issued for the first day of the month.



When the CAISO has to reallocate Station Power meter data from the On-Site Self-Supply Load ID to either the Remote Self-Supply Load ID or the Third Party Supply ID, the CAISO will charge a $200 monthly fee per Station Power meter to the portfolio owner’s SC under Charge Type 6609 – Station Power Fee.



The first step (in the application process) will be for the Generating Unit owner that wishes to self-supply Station Power to complete the Station Power Portfolio application process, and for the CAISO to approve the plans and metering schemes in consultation with the responsible UDC and the CPUC.



When this is complete, the CAISO will set up the Load IDs for all Station Power meters in the Station Power Portfolio, and the owner will be certified to begin self-supplying Station Power.



The CAISO will poll channel 1 (Demand) and channel 4 (Generation) of all CAISO certified meters, including those serving Station Power load on the day after the Trade day.



The CAISO will allocate meter data to the Remote Self-Supply and Third Party Supply Load IDs before the Preliminary Settlement Statement on the first day of the Netting Periodis issued (i.e., 38 business days after the Trade Day).


Station Power Portfolio Application Form

One-line diagrams (are required for the Station Power Portfolio Application Form) clearly showing the location and ownership of all Generating Units and Station Power meter arrangements, their connection to the CAISO-Controlled Grid or distribution system, and the status of breakers and switchgear for normal system operation.One-line diagrams should also include: The operation of the ISO meters input and output circuits.



A narrative (is required for the Station Power Portfolio Application Form) describing the proposed configuration of the Station Power Portfolio along with a description overview of the facility. This overview should include a brief description of the operation of the site such as the meters installed, description of communication circuit, the size of generation and station power load, and identify load connection with distribution or transmission grid.



(Required for the Station Power Portfolio Application Form): Revised MSA – Schedule 1 (if new meters are installed).



Required (for the Station Power Portfolio Application Form): Your 3rd party UDC must be able to see your meter data either through OMAR online or meters. Therefore, please update your MSA schedules as necessary.


Procedure: Station Power Portfolio Application

Likewise, each Station Power meter must be subject to a Meter Service Agreement (“MSA”) for CAISO Metered Entities.



Any Generating facility outside the CAISO Control Area owned by the same Corporate Entity is eligible to provide Remote Self-Supply Station Power loads, with the following conditions: Meter data for these Generating facilities shall be subject to CAISO audit to verify performance in accordance with the above requirements.



Each Station Power meter must be certified in accordance with the CAISO Tariff and all end uses served must meet the definition of Station Power.



All load served by each Station Power meter must be consistent with the definition of Station Power, and any ineligible load must have appropriate retail metering in place.Note: Under no circumstances may ineligible loads be served through a Station Power meter.

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689 Functional - Metering - - - - 2.2 Meter shall comply with ANSI standards and as modified herein

690 Functional - Metering - - - - 2.3.2

691 Functional - Metering - - - - 2.3.3.

692 Non-Functional - Metering - - - - 3.1




696 Non-Functional - - - - - - 4.3




700 Non-Functional - Metering - - - - 5.4.1 The Meter will be inspected for physical and electronic attributes as shown in Attachment 1.



Each Station Power meter must be installed per the CAISO Revenue Metering Deployment Guide located at:http://www.caiso.com/docs/2001/08/28/2001082815023715721.doc. *Link not found, error 404. * Note: This criterion can be in progress or completed at the time of application submittal. If installation is in progress and the application is complete the application will be put on-hold until the meter installation is complete and certified by a CAISO meter engineer. Once the meter installation is certified, the application will be reviewed for approval and implementation into CAISO systems.



A single Scheduling Coordinator must be assigned to both the On-Site Self-Supply and Remote Self-Supply Load ID associated with each Station Power meter.



A single Scheduling Coordinator must represent the unique load identifier assigned by the CAISO for On-Site self-supply and Remote Self-Supply associated with each Station Power meter. Generation sources in a Station Power Portfolio may have different Scheduling Coordinators, but all generation and load resources in a Station Power Portfolio must be owned by the same corporate entity.



The one-line diagrams must be clear and in pdf format. They must clearly show the location and ownership of all Generating Units and Station Power meters, their connection to the CAISOControlled Grid and/or distribution system, and the status of breakers and switchgears for normal system operation.In addition, the one-line diagrams should include: The operation of the ISO meters input and output circuits.



(Required Documentation) Station Power Portfolio Overview – A narrative describing the proposed configuration of the Station Power Portfolio along with a description overview of the facility. This overview should include a brief description of the operation of the site such as the meters installed, description of communication circuit, the size of generation and station power load, and identify load connection with distribution or transmission grid. Additionally, list any other information that requires special consideration and that would introduce the site and operation to an outsider.

Engineering Specification for Polyphase Meters (MTR 10-99


Meters approved for purchase under this Specification may not be required to have all of the specified features. ISO will specify the features for each application as necessary.


Each Meter supplied shall meet the specified minimum requirements and the requirements of Section 17, the Meter Approval Testing.


The Meter, excluding replaceable battery, shall have a minimum service life of 16 years from the manufacturer’s shipping date, or 15 years from the installation date, whichever is longer. During the service life period, the Meter shall continue to operate in full compliance with the Specification.


The annual failure rate, excluding user induced failures, shall not exceed 0.75% throughout the service life of the Meter. The failure rate is the ratio of the number of Failed Meters of a specific type, to the number of installed Meters of the same type. A Failed Meter is defined in Section 17.2 and Section 24, Definitions. If the failure rate exceeds 0.75%, this may result in removal of the Meter from the ISO - approved list for load only revenue meters.


As a minimum, the Supplier shall provide a standard warranty of three years from the date of the Meter delivery.


Supplier shall warrant that the Meter and all parts thereof furnished by Supplier, whether or not manufactured by Supplier, shall be of the kind and quality described by this Specification will be free of defects in workmanship, material, design, and quality, and shall be fit for its intended purpose.


Supplier shall warrant that when the Meter is placed in operation or used, it will perform in the manner set forth by this Specification. The Supplier shall complete all cash refunds and replacements of the Failed Meters within 60 days of Purchaser’s delivery of the Failed Meters to the Supplier.


Each Meter received by Purchaser will be tested for various physical and electronic attributes. A metering accuracy test shall be performed at the time of installation on the Purchaser’s premises.


The minimum Acceptable Quality Level (AQL) of each Meter as received at Purchaser’s facility shall meet or exceed that in Section 5.3.


The Purchaser shall accept the Meter if it meets all of the following criteria are met: The Meter passes a combined inspection for physical and electronic attributes and metering accuracy as defined in Section 5.4.


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701 Non-Functional - Metering - - - - 5.4.2 Installation accuracy tests will be performed on the Meter.

702 Non-Functional - Metering - - - - 5.4.3 The tests will be performed at full and light loads. The test point loads are shown in Table 1.

703 Non-Functional - Metering - - - - 5.4.4

704 Business Rule - Metering - - - - 5.5

705 Business Rule - Metering - - - - 6

706 Non-Functional - Metering - - - - 7.1 All energy and power measurements are as 'delivered'


708 Functional - Metering - - - - 7.2.2 ISO may request the Supplier to program Meters with a specified program.





713 Non-Functional - Metering - - - - 7.3.5 Demand intervals shall be programmable for duration of 1, 5, 10, 15, 30 or 60 minutes.





718 Non-Functional - Metering - - - - 7.4.2 Date and time shall be stored with the load profile interval data.











For acceptance of a Meter, the metering accuracy at the test points shall be within the following limits.


Any Meter that fails any of the inspections or accuracy tests will be returned to the Supplier for replacement or full return credit in accordance with Section 4., Warranties. The Supplier shall pay for all shipping and handling costs for returning the Meter.


The Supplier shall submit to ISO, for ISO’s evaluation and approval, a written request for any functional or design revision made to the Meter. Cosmetic changes, which do not affect the meter's functionality, will not require re-certification.



When power is applied to the Meter, it shall immediately begin recording total kilowatt-hours. This function shall be performed regardless of whether the Meter is programmed or not and shall not require a battery.



As a minimum, the Meter shall be programmable for fixed and/or rolling interval demand calculations on kilowatts and kilovars.


A battery shall not be required to perform demand calculations, to save the results, or to communicate the results to a handheld meter reader connected to the optical port.


The Meter shall be programmable for one minute delivered kilowatt demand (as an approximation of “instantaneous” kilowatts delivered) in addition to the rolling interval demand calculation. The one-minute demand is not required to be synchronous with the other demand quantities.


The Meter shall be programmable for rolling interval demand calculations for any optional demand quantity (see Section 7.1.2.) that ISO specifies.



The demand interval shall be composed of an integral number of subintervals. Subinterval duration shall be a programmable duration of 1, 5, 10, 15 or 30 minutes.


Demand functions shall be capable of temporary suspension for a programmable time interval after power is restored following a power outage. The length of time shall be programmable from zero to 60 minutes in one-minute intervals.


After a demand reset, further manual demand resets shall be prevented with a programmable lockout time. A demand reset from a Meter Programmer connected to the optical port is not subject to this delay and can be initiated as frequently as required.


ISO requires that the Meter provide load profile recording of interval data for 1 to 4 channels of consumption quantities.



Load profile data shall use a “wraparound” memory that stores new interval data by writing over the oldest interval data.


The load profile function shall be capable of storing and communicating a minimum of 30 days of 4 channel, 5 minute data, in addition to allowances for event recording (power outages, resets, time sets, etc.).


The load profile function shall have the capacity to count and store at least 16,000 counts in a 15-minute period of time.


Load profile data recording shall continue while the Meter is communicating with a Meter Programmer connected to the optical port.


During power line disturbances such as brownout or outage conditions, and during transportation to the installation site, the Meter shall maintain all meter data as well as time keeping functions. Display and communication functions are not required during these conditions.


The Meter shall withstand all of the following outages during a continuous five year or longer service without the need to maintain its auxiliary power system, including replacing the battery: 20 short outages per year at less than 30 seconds per outage and 40 days of continuous/cumulative outage.


During a power outage critical program and billing data shall be written to nonvolatile memory. When power is restored, data shall be returned to active memory and data collection resumed.

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732 Functional - Metering - - - - 7.6.4 Upon activation of the Test Mode, register displays shall accumulate beginning from zero.

733 Functional - Metering - - - - 7.6.5 Actuation of the billing period reset device during Test Mode shall reset the test mode registers.



736 Functional - Metering - - - - 8.1



740 Non-Functional - Metering - - - - 8.5 Time shall be displayed in the 24-hour military format.

741 Non-Functional - Metering - - - - 8.6 Date shall be displayed programmable in either Day/Month/Year or Month/Day/Year format.






747 Functional - Metering - - - - 8.8.3 Display times shall be programmable









Following a power outage, register “catch-up” time shall be a maximum of 30 seconds. During the “catch-up” time the Meter shall still calculate consumption and demand quantities. Optional outputs shall also function during this time.


During power outages, time shall be maintained with a cumulative error of no more than 2 minutes per week (0.02%).


The Meter shall record the date and time of any power outage. This data shall be available through remote interrogation of the meter.


The Meter shall have the capability of a Test Mode that suspends normal metering operation during testing so that additional consumption and demand from the tests are not added to the Meter’s totals.


The Test Mode function shall be activated by a permanently mounted physical device that requires removal of the meter cover to access, or by a Meter Programmer connected to the optical port or RS-232 port.


Activation of the Test Mode shall cause all present critical billing data to be stored in nonvolatile memory and restored at the time of exit from the Test Mode.




After a programmable time-out period, the Meter will automatically exit from Test Mode and return to normal metering.


The default Test Mode registers for an unprogrammed meter shall include as a minimum: Time remaining in the test interval, Maximum kilowatt block demand, and total kilowatt-hours.


The Meter shall have an electronic display for displaying the consumption and demand quantities. A liquid crystal display (LCD) is preferred.


Digits for displaying the consumption and demand quantities shall be 0.3-inch minimum height, and be legible in normal daylight conditions from a distance of six feet by an observer. The viewing angle shall be a minimum of +/- 15 degrees from the front of the Meter face line of sight.


Consumption and demand quantities shall be programmable to display leading zeroes in four, five, or six digits with a decimal point at any of the least significant three digits.




The meter shall be Y2K Compliant. The meter functionality will not be adversely affected as a result of the date change from 1999 to 2000, including leap year calculations.


Normal Mode—In this mode the display shall scroll automatically through the programmed displays for normal meter reading.


Alternate Mode—In this mode the display shall scroll automatically, scroll manually, or freeze for up to one minute for alternate programmed displays.


Test Mode—In this mode the display shall scroll automatically, scroll manually, or freeze for up to one minute for test quantity displays.


Display ID numbers and display sequence shall be independently programmable for each of the three modes.



Upon power-up, the Meter display shall operate in the Normal Mode. The Meter display shall operate in Normal Mode until power is disconnected, the Alternate Mode is activated, or the Test Mode is activated.


The Alternate Mode shall be initiated with a display control device that does not require meter cover removal or with a Meter Programmer connected to the optical port.


As a minimum the Meter shall provide the display quantities and items for each of the three modes as detailed in Attachment 2.


The Meter shall have programmable identifiers for the Meter ID, and the current program ID. The Meter ID shall be capable of eight alphanumeric characters.


The Meter register shall be capable of performing a self-test of the register software. As a minimum, the self-test shall be performed at the following times: Whenever communications is established to the register, after power-up, once per day


As a minimum, the following diagnostic checks shall be performed during a self-test: check the backup battery capacity, verify program integrity, verify memory integrity.


The meter shall be capable of detecting and logging that the maximum number of pulses has been exceeded during a demand interval.

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760 Functional - Metering - - - - 10.4 All software programs shall be PC DOS or Window based.



763 Non-Functional - Metering - - - - 11.2 The Optical Port shall communicate at a minimum of 9600 baud.


765 Functional - Metering - - - - 11.4 There shall be no cable connection between the optical port on the Meter cover and the register.












Any detected error or warning shall be stored in memory and an error or warning code displayed on the display. (list)


Error or warning conditions shall only be reset upon an explicit command invoked via the Meter Programmer or upon some other explicit action by the Meter Technician.


The Meter shall be capable of communicating with a handheld reader (Itron DataCap or similar) and a laptop computer through an optical port.


PC DOS or Window based programs on a laptop or handheld computer with LCD displays will be used as meter reader/programming devices (Meter Programmers). Communications with the Meter shall be through the optical port.


The Supplier shall provide all software for maintenance, programming, and operation of the Meter. The software shall include the following: field program, and Password protection to preclude 3rd party access for all levels of access EXCEPT READ-ONLY.



The protocol used for communication with the Meter through the optical port, RS-232 port or an optional modem shall be an asynchronous, byte oriented protocol.


The primary communication port to the Meter for reading and programming of the internal data shall be an optically isolated communication port per ANSI C12.13, Type 2.



The Optical Port shall be located in the front of the Meter and be accessible without removing the Meter’s cover. The Optical Port shall also be functional with the Meter cover removed.



One RS-XXX port shall be provided at the meter for bi-directional communications (with security provisions included) to computers and/or data acquisition devices. The meter or meters must have the capability for being polled every 5 minutes for data by an external program running on the Meter Data Acquisition program located at the ISO on ISO computers. An optional RS-XXX port or ports with READ-ONLY access can be provided for others desiring the data. Most buyers will probably want the optional ports. All RS-XXX ports shall be optically isolated. ISO network protocol is TCP/IP


In addition to the other items in this specification, meters used for curtailable loads shall have the following features: Additional RS232 or RS485 communication port for SCADA that functions simultaneously with the other ports.


The meter should be compatible with one or more of the following protocols for providing real-time SCADA information: Ethernet TCP/IP, Modbus, DNP 3.0, Open Protocol compatible with major RTU and IED vendors such as Valmet, System Northwest, QEI, DAQ and Siemens


ISO may specify one to two channels of pulse outputs that are proportional to the consumption quantities. The pulse output values shall be programmable with pulse durations of at least 100 milliseconds. The outputs may be either 2-wire, Form A or 3-wire, Form C configuration.


ISO may specify a programmable auxillary contact capable of being programmed to indicate End of Demand Interval (EOI).


ISO may specify an additional serial communication port consisting of a 2-wire, 20 milliamp current loop that is optically isolated from the rest of the Meter. The baud rate shall be selectable as 300/1200/2400/9600 baud as a minimum.


ISO may specify an internal modem having telephone communication at auto-baud rates up to 28.8 k-baud. The modem shall include automatic baud select, configurable answer time window, and configurable answer ring-counter. The ring detect circuitry shall not be affected by spurious voltage rises in the telephone line.


ISO may specify a kilowatt threshold relay that closes at a programmable demand value and stays closed for the remainder of the interval and until at least one complete interval does not exceed the threshold value. Transformer loss Compensation


The meter should be equipped with algorithms that properly compensate for all watt/var losses in transformer. This compensation should register no load losses whenever the transformer is energized. The compensation should properly consider copper and stray watt losses and var losses when there is load on the transformer. The algorithm can consider that the transformer operated at a single temperature point.


The meter can be ordered with an auxiliary power supply, supporting AC or DC voltages of 120/240V (ANSI). The auxiliary power input may be connected to a separate source or may be connected to any phase that is attached to the meter.

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782 Functional - Metering - - - - 13.7 Pulse outputs shall have the same accuracy as the Meter displays.




786 Functional - Metering - - - - 14.4 The Meter shall be used to meter electrical service on a continuous duty.

787 Functional - Metering - - - - 14.5 The Meter’s internal electrical connections shall be in accordance with ANSI C12.10.










797 Non-Functional - Metering - - - - 15.4 ISO may specify additional requirements for Meters used in corrosive atmospheres.

798 Non-Functional - Metering - - - - 15.5 The Socket Meter’s dimensions shall be in accordance with ANSI C12.10


The Meter shall meet or exceed the accuracy specifications contained in ANSI C12.20-1997 over its entire service life without the need for adjustment.


The Meter shall be factory calibrated by the Supplier to provide the following level of accuracy: 1) +/- 0.2% at full load at power factor of 100% 2) +/- 0.25% at full load at power factor of 50% lag 3) +/- 0.25% at full load power factor at 50% lead 4) +/- 0.25% at light load at power factor of 100%


Meter accuracy and calibration tests, both shop and field, shall require only standard test equipment. No special Laboratory-type test equipment or test procedures shall be required to assure accuracy of the Meter.


The Meter shall not creep. No pulse generation or registration shall occur for any consumption or demand quantity which depends on current while the current circuit is open except when Transformer Loss Compensation is being performed.


The Meter shall start to calculate consumption and demand quantities when the per phase current reaches the following limits: Class 20 - 10 milliamps


The Meter shall start to calculate consumption and demand quantities less than 3 seconds after power application.



The following Forms, Voltage Ratings and Classes of Meters are approved for installation on ISO system: A-Base) Forms 5A and 9A, 120 Volts, Class 20; Socket Type) Forms 5S and 9S, 120 Volts, Class 20; Switchboard Type) 2 Element and 3 Element, 120 Volts, Class 20; Rack Mounted Meter Assemblies) 2 Element and 3 Element, Class 20


All circuit boards in the Meter shall be assembled per ANSI/IPC-610A, Class 2 Standards. They shall be designed to meet ISO’s environmental and electrical testing requirements and the service life and performance expectations detailed in this Specification.


Gold pins encased in an elastomer or carbonized contacts or better construction shall be used to connect the LCD display to the register circuit board.




The Meter register shall be powered from the line side of the Meter and shall have provision for external backup power. Neither the Normal power supply nor the Backup Power Supply (when so equipped) shall be fused.


The clock internal to the Meter shall be accurate within 2 minutes per week (0.02%) when not synchronized to the line frequency and shall be resettable through the ISO communications interface. ISO will transmit a periodic master synchronizing signal to the meter


When the Meter design requires a battery as auxiliary power supply, the requirements of Section 7.5. shall apply


The Meter shall be designed in such a way that conducted or radiated electromagnetic disturbances as well as electrostatic discharges do not damage nor substantially influence the Meter.


The Meter shall not generate conducted or radiated radio frequency noise, which could interfere with other equipment.


The Meter shall meet FCC Part 15 Class A, Radio Frequency Interference Standard for computing devices.


The Meter shall not pose any danger when operating under rated conditions in its normal working position. Particular attention shall be paid to the following: a) Personnel protection against electric shock; b) Personnel protection against effects of excessive temperature; c) Protection against the spread of fire; d) Protection against penetration of solid objects, dust or water


All parts shall be effectively protected against corrosion under normal operating conditions. Protective coatings shall not be damaged by ordinary handling nor damaged due to exposure to air. The meter shall be capable of operating in atmospheres of 95% relative humidity condensing.


The functions of the Meter shall not be impaired, the appearance of the Meter shall not be altered, and the legibility of the Meter nameplate and other labels shall not be reduced due to exposure to solar radiation throughout the service life of the Meter.



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799 Non-Functional - Metering - - - - 15.6 The nameplate information shall comply with the minimum requirements of ANSI C12.10



802 Functional - Metering - - - - 16.3 Removal of the Meter cover shall be required to activate the Test Mode. See section 7.6r.


804 Functional - Metering - - - - 16.4.1 Read Register ---user can only READ billing and load profile data.

805 Functional - Metering - - - - 16.4.2 Read Register—user can only read billing and load profile data, and perform a billing period reset.




810 Functional - Metering - - - - 17.2 A Meter shall be designated as failed if: Failure of the Meter to perform all of the specified functions










820 Functional - Metering - - - - 17.12 Clock accuracy test: This test shall be conducted with the register in the battery carryover mode



Operation of the billing period demand reset mechanism shall require breaking of a mechanical sealing device. Use of common utility - Type sealing devices shall be accommodated.


The Meter shall be programmable by the Meter Programmer with up to four unique passwords to prevent unauthorized tampering by use of the optical port or the optional modem. Access rights and capabilities shall be individually programmable for each password. The Meter shall accept multiple requests from different sources without error, lockup or loss of data. The desirable password would consist of six Alpha-Numeric characters.



At least four levels of security shall be available for the Rate Development Program and the Field Program. These levels include:




Read/Modify Register—user can perform functions listed in 16.4.1 and 16.4.2, plus download meter configuration files and operate other features of the Field Program.


Read/Modify/Program Register—user can perform functions listed in 16.4.1, 16.4.2 and 16.4.3, plus develop meter configuration files and operate additional features of the Rate Development Program.


In addition to the applicable testing requirements of the ANSI C12 standards, the qualification tests specified in this Section shall be conducted by the Supplier to confirm correct operation of the Meter



A Meter design will be rejected if: When one Meter fails while performing one test procedure and a second Meter fails performing another test procedure


Test Setup: The Meter shall be connected to its normal operating supply voltage with a fully charged Power Failure Backup System. The Meter shall be energized throughout the duration of the test procedures, unless otherwise stated


Functional test (no load): This test confirms the operation of the Meter functions in accordance with the Specification


The accuracy of the Meter shall be tested for all combinations of the following conditions: a) At ambient temperature, 85 C, and -20 C; b) At power factors of 100%, 50% lag, and 50% lead; c) Current(Amps): 0.15, 0.25, 0.5, 1.5, 2.5, 5.0, 10.0, 15.0, 18.0, 20.0


The Meter shall be tested at line voltages ranging from 80% to 120% of rated voltage with 10% increment under the following load conditions: a) Full load at power factor of 100%; b) Light load at power factor of 100%


Twelve tests shall be conducted using the following sequence: a) Energize the Meter; b) Simulate a power loss of 0.5 cycles at 60 hertz; c) Lengthen each succeeding simulated power outage by 0.5 cycles until a duration of 6.0 cycles is attained; d) The start of each successive test shall be delayed by one minute. To pass this test the Meter shall operate as specified with no observed anomalies


The test shall be conducted using the following sequence: a) Energize the Meter at full load for two hours; b) De-energize the Meter for 24 hours; c) Verify the integrity of programs and metering data stored in memory


The test shall be conducted using the following sequence: a) Energize the Meter and verify correct operation; b) Slowly lower the line voltage at a rate of 1 volt per second to 80% of nominal voltage; c) Operate the Meter at this voltage level for 6 hours; d) Verify correct Meter operation. If the meter comes up with the power outage detection flag, this should be recorded; e) Lower the line voltage at a rate of 1 volt per second from 80% to 50% of nominal voltage; f) Operate the Meter at this voltage level for 6 hours; g) Verify correct operation of the Meter and the Power Failure Backup System


The Meter shall be tested with the battery disconnected and an auxiliary dc power supply connected to the battery carryover circuit. The dc power shall be applied at 105%, 100% and 95% of nominal battery voltage. Each voltage level shall be maintained for at least 6 hours prior to recording time variation


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821 Functional - Metering - - - - 17.13 Meter accelerated temperature cycling tests: The Meter cover shall be removed during this test









830 Non-Functional - Metering - - - - 18.1 Hazardous voltages shall not be easily accessible with the meter cover removed.



833 Non-Functional - Metering - - - - 18.4 Materials used in the construction of the Meter shall not create a fire hazard.



Meter accelerated humidity cycling tests: The Meter cover shall be removed during this test, or a meter cover with a large hole at the bottom may be substituted


Meter insulation level tests: a) The Meter shall not be energized for this test; b) The insulation between power line voltage and current carrying parts and any other metallic or conductive part shall be tested by applying 2500 volts rms, 60 Hz for a period of one minute; c) To pass this test the leakage current shall not exceed five milliamp for the duration of the test and the Meter shall operate after completion of the test


Meter voltage withstand tests: a) The Meter shall be energized but not loaded during the test; b) The test shall be conducted in accordance with the latest revision of ANSI C37.90.1; c) The oscillatory test wave shall be applied at a repetition rate of 100 tests per second for 25 seconds; d) The test signal shall be applied in both the common and transverse modes; e) The test shall be conducted on all voltage, current, and optional equipment inputs and outputs; f) This test will be performed two times with a maximum period of 1 minute between tests


Meter withstanding fast voltage transients tests: a) The Meter shall be energized but not loaded during the test; b) This test shall be conducted in accordance with the latest revision of ANSI C37.90.1; c) The uni-polar test wave shall be applied at a repetition rate of 100 tests per second for 25 seconds; d) The test signal shall be applied in both the common and transverse modes; e) The test shall be conducted on all voltage, current, and optional equipment inputs and outputs; f) This test will be performed two times with a maximum period of 1 minute between tests


Meter withstanding powerline voltage and current surge tests: a) The meter shall be energized but not loaded during the test; b) The test shall be performed using the uni-polar and the ring waveform specified in the latest revision of ANSI C62.41; c) The test surges shall be applied to the power line in both the normal and common modes; d) The following number of surges shall be applied at the indicated voltages: 12 surges at 6 kV, 12 surges at 5 kV, and 36 surges at 4 kV; e) The first test surges at 5 kV and 6 kV shall be injected at 0 degrees on the positive half-cycle of the waveform. Each successive test surge shall be shifted 15 degrees on the positive half-cycle of the waveform up to 180; f) The first test surge at 4 kV shall be injected at 0 degrees on the positive half-cycle of the waveform. Each successive test surge shall be shifted 15 degrees on both the positive and negative half-cycles of the waveform up to 360; g) Sufficient time shall be allowed in between test surges for the electronic components to return to normal operating temperatures. A minimum of 5 minutes shall be allowed between each surge test; h) The applied test signals shall be monitored and recorded. The Meter under test shall be monitored to confirm that correct operation is maintained; i) After the tests each meter shall be inspected for visible damage, such as signs of arcing, etc


Electrostatic Susceptibility Test: a) This test shall be tested in accordance with the latest revision of Military Handbook DOD-HDBK-263; b) The test generator shall simulate a human body with a capacitance of 100 pico-farads and a series resistance of 1500 ohms; c) The test probe shall be a 3/8 inch rod with a rounded tip


Visual inspection tests: a) This test shall be performed after all of the other tests except the Shipping Test have been performed; b) Visual inspection shall be performed for all electronic circuit boards in the Meter; c) To pass this test the Meter shall have no defect that is rejectable per IPC-610A, Class 2 Standards on any electronic circuit board


Shipping Test: a) The Meter shall not be energized during this test, but shall be programmed and operating in the power Backup mode; b) The packaged Meter shall be subjected to The National/International Safe Transit Association Pre-shipment Test Procedures, Project lA; c) The packaged Meter shall be subjected to American Society for Testing and Materials (ASTM) Standard D-999 latest revision, Method B, Single Container Resonance Test. Test intensities, frequency ranges and test duration's shall meet or exceed the recommended values of ASTM D-999



All accessible conductive parts on the exterior of the meter and conductive parts that are accessible upon removal of the meter cover shall be electrically connected to the Meter grounding tabs. All connections in the grounding circuit shall be made with an effective bonding technique.


No materials that are toxic to life or harmful to the environment shall be exposed in the Meter during normal use.


G2


H2




Telemetry










845 Functional - Metering - - - - ISO Meter Maintenance Form

847 Business Rule - Metering - - - - VI

848 Functional - Metering - - - - VI

849 Functional - Metering - - - - VI

850 Business Rule - Metering - - SLIC - V Requests and secures SLIC outage number(s) for the Meter work.

851 Business Rule - Metering - - - - V Identifies to CAISO the name of the entity performing the Meter work

852 Business Rule - Metering - - - - V


854 Business Rule - Metering - - - - V Collects at least 45 days of meter data in a HHF Format before work is started

855 Business Rule - Metering - - - - V Retrieves and Stores Meter data in non volatile, electronic memory


857 Business Rule - Metering - - SLIC - V


Manual access for changing data or reprogramming shall, require the physical removal or breaking of an ISO seal by ISO-Authorized personnel. This applies to all Metering Equipment, including recorders, Data Servers and other Associated Devices.


Each Meter must be capable of being polled simultaneously by more than one user, without loss of data, interference or lockup.


No loss of data shall occur as a result of the following events within design specifications: Power outages, frequency changes, transients, harmonics, reprogramming, and reading; Environmental factors - - Dampness, heat, cold, vibration, dust.


19.4. Five-minute interval data for the most recent 60 day period shall always be available and accessible via the communications interface or the optical interface.


The Manufacturer and its sub-suppliers shall provide for in-plant inspections of material, inspections of the testing facility and audits of the Supplier’s quality control by ISO as required


Delivery will be according to an agreed delivery schedule The Supplier and the Purchaser will negotiate a delivery schedule at the time of purchase. The Meters shall be delivered as complete assembled units, including cover and battery, ready for programming.


22.1.1. An instruction booklet detailing the necessary procedures and precautions for installation of the Meter shall be provided for each Meter purchased. This booklet is intended for use by field personnel during initial installation and shall be written in the style of a step by step outline. A technical/maintenance manual and repair manual shall be provided for each Meter. These manuals shall be sufficiently detailed so that circuit operation can be understood and equipment repair facilitated.


The Manufacturer shall provide a complete set of manuals detailing the operation of the Field Program to ISO. These manuals shall explain to a person with only basic computer knowledge how to generate and download Meter configuration files.


This specification shall be used in conjunction with the following publications. The revisions in effect when bids are awarded shall apply.

Numerous functional requirements are specified (100+) which must be recorded for each ISO meter maintenance including: meter, installation, data, battery, firmware, and protocol information, etc.

G004-Scheduled Communication Outages

Metered Entities should notify MDAS Operations by email (e-mail address is [email protected]) 72 hours before the communication outage is scheduled to occur, then follow-up by contacting MDAS Operations directly.


MDAS Operations will test and work with Metered Entity until communication link is successfully re-established.


If necessary, MDAS Operations will advise the Metered Entity that the duration of the scheduled outage requires that a manual read should be retrieved at intervals determined by MDAS Operations.

G005-Routine Testing/Maintenance of CAISO Meters



Identifies to CAISO the name of the entity whose CAISO Authorized inspector will be inspecting the Meter work


Retrieves both visual and electronic meter reads before and after the tests, to reduce the need for data estimation




Contacts CAISO Meter Engineering at least 5 days before meter work is scheduled, and obtains CAISO’s concurrence to proceed with scheduled work.


Contacts the CAISO Meter Engineer assigned to that site before meter work begins in order to receive approval from real time operations that the requested SLIC outage has been activated, and to ensure the CAISO meter has been read and data is validated

G2


H2




Telemetry


859 Business Rule - Metering - - - - V Removes/installs CAISO Meter system seals.



862 Business Rule - Metering - - RMDAPS - V+D30 Schedules Meter Inspector Meter work with RMDAPS.

863 Business Rule - Metering - - SLIC - V Verifies the issue and approval of SLIC ticket(s) for planned Meter work.

864 Business Rule - Metering - - - RIG V Informs RIG Engineers of scheduled Meter work approvals.

865 Business Rule - Metering - - - - V Reviews and approves submitted Meter work plan(s).

866 Business Rule - Metering - - - - V Polls affected CAISO Meter(s) before and after the Meter work.

867 Business Rule - Metering - - RMDAPS - V Conducts communication tests between the Meter and RMDAPS.


869 Business Rule - Metering - - - - V Audits CAISOME after major changes for continued Meter compliance.

870 Business Rule - Metering - - - - V Ensures required documentation has been completed and received for Meter work performed.

871 Non-Functional - Metering - - - - VI Planned periodic Meter work shall be scheduled with CAISO at least five (5) business days in advance.

872 Non-Functional - Metering - - SLIC - VI

873 Non-Functional - Metering - - SLIC - VI

874 Functional - - - - SLIC - VI

875 Non-Functional - Metering - - - - VI

876 Non-Functional - Metering - - - - VI

877 Business Rule - Metering - - SLIC - VI

878 Business Rule - - - - - RIG VI


Ensures that at least 45 days of data in HHF format from the CAISO Polled meter is retrieved before any changes, (testing, programming, etc.) are made to the meter.



Performs or observes Meter Technician performance of Meterwork, and completes CAISO’s required documentation.


Submits Meter documentation to CAISO within five (5) business days following completion of the Meter work.








Reviews submitted CAISO Site Verification Data sheets and other related documentation such as; HHF files, meter data files, and program files.





CAISO Outage (SLIC) Requests are required for all CAISO-Metered units, using the CAISO SLIC 72-Hour notice.


Planned periodic maintenance and/or tests performed on Intertie and certain Intratie Meters must also be coordinated with the CAISO SLIC 72-Hour notice


Meter work activities that affect real time telemetry between the site and CAISO require CAISO real time operations authorization through the submittal of a SLIC Outage Request .


Meter technician and/or ISO Meter Inspector will work in compliance with the site’s clearance, safety, and operations rules.


They will also work within CAISO operating procedure during a CAISO declared Restricted Maintenance Operation period. See procedure located at http://www.caiso.com/docs/2002/03/15/2002031510081611112.pdf


The CAISOME will make the SLIC outage number(s) available to CAISO personnel and to the Meter Inspector upon request.


Each day of the planned maintenance and prior to beginning that days Meter work, the Meter Inspector will contact the assigned Meter/RIG Engineer to poll and verify Meter(s) and verify real time telemetry to the CAISO EMS.

G2


H2




Telemetry

879 Business Rule - Metering - - - RIG VI



882 Business Rule - Metering - - - RIG VI

883 Business Rule - Metering - - SLIC - VI.A

884 Business Rule - Metering - - - - VI.A

885 Business Rule - Metering - - - - VI.A

886 Functional - Metering - - - - VI.A



889 Non-Functional - Metering - - RMDAPS - VI.A

890 Functional - Metering - - - - VI.A Test only one meter at a time


892 Business Rule - Metering - - - - VI MDAS OPERATIONS Identifies corrupt or missing meter data.



895 Functional - Metering - - - - 1

896 Non-Functional - Metering - - - - A.1

897 Functional - Metering - - - - A.1

898 Non-Functional - Metering - - - - C.1

899 Business Rule - Metering - - - - G009-ISO Meter Inspection V


During a period of Restricted Maintenance Operation and/or staged alerts, warnings or emergencies, the Meter Inspector will contact the assigned Meter/RIG Engineer to receive express permission immediately before disabling equipment or starting work.


The CAISOME will provide CAISO personnel with the name of the entity it has contracted to perform the Meter work.


The Meter Inspector will advise CAISO when testing will commence, the present energy flow (if any), and the anticipated length of the test(s).


The Meter Inspector will advise the RIG or Meter Engineer if real-time energy levels change from manually represented levels.


At a minimum, the ISO Meter Inspector requests the site to produce a SLIC outage number and provides notification according to section VI. B. prior to starting any Meter work.


ISO Meter Inspector must be on site to observe the Meter work. In some cases, the ISO Meter Inspector will also perform the Meter Technician's role.


In cases where a Backup Meter is in place, it is recommended that the Backup Meter be tested first so its data may later be used to plug data gaps inserted on the main Meter during testing.


In cases where Parent/Child Meter relationships exist, it may be desirable to test the Meter with the least number of inputs first, and continue until the Meter with the greatest number of inputs is tested last


The Meter Inspector retrieves Meter reads and records Meter data from affected Meter(s) before and after a test and collects an HHF file of 45 days prior to working on any CAISO-polled Meter.


The Meter Inspector also retrieves the Meter’s configuration image file and submits this information to the Meter Engineer assigned to that site.


If RMDAPS did not read the data from a polled meter, then the Certified Meter Inspector must send an HHF file to the CAISO Meter Engineer within the next 5 business days or sooner



Meter accuracy tests should be performed with the Meter isolated from its instrument transformers, and operating on its Test Mode to prevent erroneous telemetry signals and corrupted energy reports.

G006-Validation, Estimation and Editing


MDAS OPERATIONS performs the estimations as defined in Appendix G 2.3 of the Metering Protocol if the corrupt or missing data is for a period of one (1) hour or less and a point to point linear interpolation is possible.


MDAS OPERATIONS edits the data with the estimated values and validates the results Note: If point to point interpolation is not possible or the gap is greater than an hour, the CAISO Metered Entity provides MDAS OPERATIONS at (916) 351-4431 with valid data to edit the error.

G007-CAISO Metering Guideline Netting

During the development of the Installation proposal, a netting strategy is created. A successful way to document the strategy is to build a matrix that identifies the sites, IP address, port numbers, Meter Device IDs, Primary KWH Constant, display sequence, and netting strategy.

G008-CAISO Metering Guideline Manual Meter/Recorder Reading

Manually read meter/recorder and forward the MDEF (.mv9) or hff files to MDAS Operations. Files are expected as granted by the exemption and should be sent a minimum of every 14 days.


Per G001 and G005, it is recommended that the Technician take a manual read of each meter that is to be inspected, before testing begins.


When a network communication failure between MDAS and the meter/recorder threatens to extend beyond 3 days, the Metered Entity should schedule a manual-read of the measurement to minimize the possibility of data loss.

The ISO Authorized Inspector has the authority to audit and verify any metering installation that is either ISO approved or is seeking ISO approval.

G2


H2




Telemetry



903 Business Rule - - - - - - G009-ISO Meter Inspection V

904 Business Rule Metering - - - - G009-ISO Meter Inspection V

905 Business Rule - - - - - G009-ISO Meter Inspection V

906 Business Rule - - - - - - G009-ISO Meter Inspection V

907 Business Rule - - - - - G009-ISO Meter Inspection VI

909 Business Rule Metering - - - - G009-ISO Meter Inspection VI

910 Business Rule - Metering - - - - G009-ISO Meter Inspection VI The ISO Meter Engineer will schedule the work on the MDAS Calendar.911 Business Rule - Metering - - - - G009-ISO Meter Inspection VI

912 Business Rule - Metering - - - - G009-ISO Meter Inspection VI


914 Business Rule Metering - - - - G009-ISO Meter Inspection VI The ISO Authorized Inspector shall display his/her ISO badge while at the ISO Metered Entity’s facility.





919 Functional Metering - - - - G009-ISO Meter Inspection VI

920 Functional Metering - - - - G009-ISO Meter Inspection VII.A.ii

921 Functional - Metering - - - - G009-ISO Meter Inspection VII.A.iii




926 Functional - Metering - - - - G009-ISO Meter Inspection VII.A.iv Voltage transformers should comply with ANSI 0.3 Accuracy Class for metering voltage transformers.

927 Functional - Metering - - - - G009-ISO Meter Inspection VII.B.iii Each meter in the metering circuit shall be provided with its own test switch.928 Functional - Metering - - - - G009-ISO Meter Inspection VII.B.iii.8 When possible the meter accuracy testing shall be performed when the unit is offline.929 Functional - Metering - - - - G009-ISO Meter Inspection VII.B.iv The recommended practice will be to test the meter on-site and with its test switch.

The ISO Authorized Inspector must have approval from ISO Meter Engineering prior to seeking access and must comply with local safety and policy requirements when performing work within the ISO Metered Entity’s facilities.

The ISO Authorized Inspector shall have the authority to work in or inspect any area associated with the ISO revenue metering circuit. This includes the areas where the instrument transformers are installed, the secondary instrument transformer circuit, the ISO revenue metering enclosure and, where implemented, the ISO local meter data server.

The ISO Authorized Inspector shall also have access rights to any area where the ISO meter data communication circuits are routed.


The ISO Metered Entity has the right to escort the ISO Authorized Inspector to any area of their facility and to witness any test requested by the ISO Authorized Inspector.


The ISO Metered Entity shall assist the ISO Authorized Inspector when access is required to areas of the facility which the ISO Metered Entity or ISO Authorized Inspector deem to be critical areas or areas having extreme safety risks.

The ISO may exercise the option of performing inspection and certification of meters at ISO interties, intraties, governmental agencies and non-ISO metered entities.


The ISO Authorized Inspector shall be responsible for contacting the ISO Metered Entity to schedule an initial installation verification test to see if the metering facility meets ISO certification.


The ISO Authorized Inspector shall notify ISO Meter Engineering of all scheduled visits to the ISO Metered Entity’s facilities where the sole purpose is to perform the initial certification.

The ISO Authorized Inspector shall provide the ISO at least a five (5) day notice and receive confirmation from the ISO prior to proceeding with the inspection to ensure the ISO Authorized Inspector has all the pertinent data needed for the initial certification.

The ISO Authorized Inspector must be certified by ISO to perform installation verifications and audits for ISO.


The ISO Authorized Inspector must display his/her credentials (i.e. ISO-provided badge) to the ISO Metered Entity’s representatives to obtain access to the facility.


ISO Engineers may perform periodic audits. The ISO will contact companies providing ISO Meter Inspection Services in the event their services are desired.

Documentation from all ISO authorized inspection or maintenance work shall be submitted to the ISO within five (5) business days.

Any installation failing ISO certification should be so documented on the site verification form and the form sent to ISO within five (5) business days.


The ISO Authorized Inspector shall also contact the ISO Metered Entity primary or secondary contact and ISO prior to leaving the site to inform them of any certification failures.


For existing facilities that have insufficient data to establish instrument transformer accuracy, the Inspector shall provide a written list of the data required from the ISO Metered Entity to complete the certification package documentation.


The person completing this procedure shall have a working knowledge of the instrument transformers, meters, local data server, and other associated metering equipment as well as being knowledgeable of ISO certification guidelines.

The (Instrument Transformer) nameplate data should include the following information: Manufacturer, Type, Current Transformer Ratios, Burden Rating, Rating Factor, BIL, and Accuracy Class.

Current transformers shall comply with ANSI 0.3 or 0.15 Accuracy Class for metering current transformers for B0.1 through B1.8 burden ratings.

For existing facilities, ISO-approved correction factor algorithms may be used to compensate for worst than ANSI 0.3 Accuracy Class.

If the CTs are not accessible due to energized components or extensive disassembly is required that may impact plant availability, note the unavailability and request the ISO Metered Entity to identify a scheduled outage when the CT nameplate data may be accessed safely. Such schedule shall be subject to ISO approval.

G2


H2




Telemetry

930 Functional - Metering - - - - G009-ISO Meter Inspection VII.D.i Circuit burdens shall be defined in the ISO Metered Entity’s documentation and verified in the field.

931 Non-Functional - Metering - - - - G009-ISO Meter Inspection VII.E.i

932 Functional - Metering - - - - G009-ISO Meter Inspection VII.E.ii The revenue meter demand reset and cover shall be sealed.933 Functional - Metering - - - - G009-ISO Meter Inspection VII.E.ii The revenue meter test switch shall be sealed.934 Functional - Metering - - - - G009-ISO Meter Inspection VII.E.ii

935 Functional - Metering - - - - G009-ISO Meter Inspection VII.E.iii

936 Functional - Metering - - - - G009-ISO Meter Inspection VII.E.iii Instrument transformer secondary compartments shall be secured.937 Functional - Metering - - - - G009-ISO Meter Inspection VII.E.iii

938 Functional - Metering - - - - G009-ISO Meter Inspection VII.E.iv ISO approved seals and locks shall be utilized where seals and locks are required.939 Functional - Metering - - - - G009-ISO Meter Inspection VII.F.i

940 Functional - Metering - - - - G009-ISO Meter Inspection VII.F.ii

941 Functional - Metering - - - - G009-ISO Meter Inspection VII.F.iii

942 Functional Metering - - - - G009-ISO Meter Inspection VII.F.iii

943 Functional - Metering - - - - G009-ISO Meter Inspection VII.G The inspector shall completely fill out the Site Verification Data Sheet.944 Functional - Metering - - - - G009-ISO Meter Inspection VII.G

945 Functional - Metering - - - - G009-ISO Meter Inspection VII.G



948 Functional - Metering - - - - G009-ISO Meter Inspection VII.G The inspector shall verify the service voltage and the type of connection (Delta or Wye).949 Functional - Metering - - - - G009-ISO Meter Inspection VII.G








957 Functional - Metering - - - - G009-ISO Meter Inspection VII.G The inspector shall verify that there is a test switch for each meter in the ISO metering circuit.

958 Functional - Metering - - - - G009-ISO Meter Inspection VII.G The inspector shall verify that the meter communicates properly with the ISO MDAS System.


960 Functional - Metering - - - - G009-ISO Meter Inspection VII.G The numbers on the seals shall be recorded on the appropriate boxes in the Site Verification Sheets.


The NEMA enclosures containing the ISO meter and optional local meter data server and DAC if applicable, shall be ISO limited access and locked.

Some ISO approved meters can be secured and used without being placed in a NEMA enclosure. These meters shall also be locked and secured with an ISO seal.

The (test switches) shorting switches for the current circuit and the voltage switches (if one exists) shall be sealed to prevent either an open or short circuit and loss of revenue data.

Where there is more than one meter in the metering circuit, there shall be a separate test switch for each meter.

The ISO Authorized Inspector shall complete a set of ISO-approved site verification forms for each ISO meter.

If there are any discrepancies between the ISO certified drawings on file and the actual metering circuit then the ISO Authorized Inspector shall document and revise ISO certified drawings, notify ISO and give the ISO Metered Entity a Notice of Violation within 24 hours. ISO will then make a determination of other actions to take including revocation of ISO certification.

Any violations or discrepancies detected during the initial test or periodic audit as detailed in this document shall be documented on the site verification forms.


The ISO authorized Inspector shall also notify ISO and give the ISO Metered Entity a notice of non-conformance.

The inspector shall verify and record on the Site Verification Forms the meter type and its serial number.

The inspector shall verify the nameplate data on the current and voltage transformers against what is submitted on the ISO Metering Certification Form.

The inspector shall verify the wiring of the current and voltage transformers, making sure that the phasing is correct.

The inspector shall verify the amount of connected burden on the instrument transformers either through measurement or by calculation if the secondary wiring is dedicated to the ISO meter.

The inspector shall verify the meter program, including the device ID, Ke values, register constant, display sequence, and recorder configuration.

The inspector shall perform or witness performance of the meter accuracy tests and note the calibration date on the meter test standard.

The inspector shall verify any transformer and/or line loss compensation that may be applied in the meter.

The inspector shall check the generation or load indicated by the ISO meter against the ISO Metered Entity's instrumentation.

The inspector shall use the proper meter software package to check the phase angle, voltage, current and the recorder operation check.

If the meter does not provide phase angles a separate test shall be made for proper phase angles, voltage, current, and submitted to ISO.

The inspector shall record the current, voltage, and phase angle on the Site Verification Forms or attach a printout from the meter obtained using the meter's software.

The inspector shall check the external power source transfer relay and that the battery is connected to the meter.

The inspector shall install ISO Meter Seals on the meter, test switch, and any other location requiring a meter seal to properly secure the meter installation.

The inspector shall provide or download the program information from the meter and submit to the ISO along with the other documentation.

G2


H2




Telemetry

962 Business Rule - - - - - - G009-ISO Meter Inspection VII.G

963 Non-Functional - - - - - - G009-ISO Meter Inspection VII.G All documentation must be submitted to the ISO within five (5) business days of the inspection.

964 Non-Functional - Metering - - - - G009-ISO Meter Inspection VII.G

965 Business Rule - Metering - - - - G010-Exemption from Compliance VI

966 Business Rule - Telemetry - - - - G010-Exemption from Compliance VI

967 Business Rule - - - - - - G010-Exemption from Compliance VI








975 Business Rule - Metering - - - - G012-ISO Meter Audit V






981 Business Rule - Metering - - - - G012-ISO Meter Audit VI


984 Business Rule Metering - - - - G012-ISO Meter Audit VI

985 Non-Functional - Metering - - - - G012-ISO Meter Audit VI

986 Functional - Metering - - - - G012-ISO Meter Audit IX The owner of the CAISO site will maintain security of the CAISO meter or meters.987 Functional - Metering - - - - G012-ISO Meter Audit IX The meter ring and test switch shall be sealed.988 Functional - Metering - - - - G012-ISO Meter Audit IX

989 Functional - Metering - - - - G012-ISO Meter Audit IX

990 Functional - Metering - - - - G012-ISO Meter Audit IX Instrument transformer secondary compartments shall be secured.991 Functional - Metering - - - - G012-ISO Meter Audit IX

992 Functional - Metering - - - - G012-ISO Meter Audit IX CAISO seals shall be utilized where seals are required.993 Non-Functional - Metering - - - - 8.3

The Inspector shall complete Site Verification Data Sheet and indicate the facility has passed or failed the Certification Criteria.

The documentation for any visit after the initial certification shall be submitted to the ISO within five (5) business days from the date of the visit.

When deciding to issue an exemption, the ISO will ask the following question: Does the exemption request compromise the accuracy and integrity of the meter data or system?

When deciding to issue an exemption, the ISO will ask the following question: Does the exemption affect the speed or integrity of the communication system?

When deciding to issue an exemption, the ISO will ask the following question: Are the ISO requirements unnecessary, impractical, or uneconomic for the Metered Entity?

When deciding to issue an exemption, the ISO will ask the following question: The economic impact on the ISO Metered Entity?

When deciding to issue an exemption, the ISO will ask the following question: Is the request for a temporary or permanent exemption?

When deciding to issue an exemption, the ISO will ask the following question: What is the time required to install ISO approved metering system and communication?

When deciding to issue an exemption, the ISO will ask the following question: What is the time allowed for the Metered Entity to establish the accuracy class of its instrument transformers used with the meters?

When deciding to issue an exemption, the ISO will ask the following question: What is the megawatt output and strategic importance of the generator?

When deciding to issue an exemption, the ISO will ask the following question: How is security and integrity of the metering and communications circuits?

When deciding to issue an exemption, the ISO will ask the following question: Where is the plant location in terms of remoteness and communication accessibility?

The CAISO Meter Engineer has the authority to audit and verify any metering installation that is CAISO approved or seeking CAISO approval.

The CAISO Meter Engineer shall also have access authority to all CAISO approved metering installations.

The CAISO Meter Engineer shall have the authority to work in or inspect any area associated with the CAISO revenue metering circuit. This includes the areas where the instrument transformers are installed, the secondary instrument transformer circuit, the CAISO revenue metering enclosure and, where implemented, the CAISO local meter data server.

The CAISO Meter Engineer shall also have access rights to any area where the CAISO meter data communication circuits are routed.

The CAISO Metered Entity shall assist the CAISO Meter Engineer when access is required to areas of the facility which the CAISO Metered Entity or CAISO Meter Engineer deem to be critical areas or areas having extreme safety risks.

The CAISO may exercise the option of performing inspection and certification of meters at CAISO interties, intraties, and governmental agencies.

Meter Engineering will send a request by email or by phone to the site owner to conduct a site audit prior to visiting the site.

Meter Engineering will inform MDAS Operations of the scheduled site audit using the Fieldwork Calendar, so that they can be prepared to provide meter-polling support, if necessary.


The CAISO Meter Engineer must display his/her site authority to perform work at the CAISO Metered Entity’s facility.

The designated CAISO Meter Engineer shall update the appropriate metering files and the Tracker data base within 15 days.

Some CAISO approved meters can be secured and used without being placed in a NEMA enclosure. These meters shall also be secured with a CAISO seal.

The (test switches) shorting switches for the current circuit and the voltage switches (if one exists) shall be sealed to prevent the loss of revenue data.

Where there is more than one meter in the metering circuit, there shall be a separate test switch for each meter


The display shall provide Six digits for display of the consumption and demand quantities with decimal points for the three least significant digits

G2


H2




Telemetry

993 Functional - Metering - - - - G012-ISO Meter Audit IX

994 Non-Functional - - - - RIG 6.7 The display shall provide Three digits for numeric display identifiers (ID numbers)

994 Non-Functional - - - Intermittent - RIG 6.7 The display shall provide Three digits for numeric display identifiers (ID numbers)

994 Non-Functional - Metering - - - - 8.3 The display shall provide Three digits for numeric display identifiers (ID numbers)

995 Functional - Metering - - - - 8.3 The display shall provide Alternate and Test Mode Displays

996 Functional - Metering - - - - 8.3 The display shall provide Continuous potential indication for each phase

997 Functional - Metering - - - - 8.3 The display shall provide End of interval indicator

998 Functional - Metering - - - - 8.3 The display shall provide Visual representation of the magnitude of the power flow

999 Functional - Metering - - - - 8.3 The display shall provide Visual representation of the magnitude of the reactive power flow

1000 Functional - Metering - - - - 8.3 The display shall provide Announciators for use with the consumption and demand quantities

1001 Functional - Metering - - - - 9.4 Error code displays shall freeze the display



1004 Functional - Metering - - - - 11.5 The meter shall be capable of being read and programmed through the RS-XXX port

1005 Functional - Metering - - - - 11.5 The meter shall support and be compatible with ISO “REMnet” communication chains


1007 Functional - Metering - - - - 14.7 The choice of clock mode shall be programmable between internal and line frequency modes





1012 Functional - Metering - - - - 14.8 No fuse external to the battery shall be installed in the battery circuit




1016 Functional - Metering - - - - 14.8 The Supplier shall provide Material Safety Data Sheets upon Purchaser’s request



The display shall provide Six digits for display of the consumption and demand quantities with decimal points for the three least significant digits













Warning code displays shall be programmable to one of the following choices: a) Freeze the warning code on the display b) Ignore the warning code (not displayed) c) Warning code display at the end of the Normal, Alternate, or Test Modes display sequences


The meter shall be capable of being polled simultaneously by more than one entity on one or more of its ports without loss of data, interference, lockup or other such problems. In all cases, priority servicing shall be given to the ISO-required RS-XXX port




Meter RS-XXX port to high speed digital (or lease line), ISDN, or Frame Relay to ATM Cloud POP to ISO located Meter Data Acquisition System



Internal Mode: The clock shall always synchronize with its own internal crystal, as a default in the absence of line frequency


Line Frequency Mode: The clock shall synchronize with the line frequency until an outage occurs. During the outage, the clock will then synchronize with its own internal crystal. When power returns, the clock shall resynchronize with the ISO’s master synchronizing signal and follow line frequency


The battery shall be secured with a holder securely attached to the Meter. The battery holder and electrical connections shall be designed to prevent the battery from being installed with reversed polarity


Replaceable batteries shall be easily accessible by removing the Meter cover. Battery replacement while the Meter is in service shall not interfere with any of the specified functions



The meter battery shall provide a minimum carryover capability at 23 C for the functions listed in Section 7.5. and have a 15 year shelf life


The following information shall be clearly identified on the battery: Manufacturer, Date of Manufacture (year & month or year & week), Polarity, Voltage Rating, Type


The Supplier shall provide battery handling instructions, safety precautions, and disposal instructions upon Purchaser’s request



The method of securing the Socket Meter to the meter socket shall be with either a sealing ring or a high security-sealing device


The billing period demand reset device shall accommodate a standard Utility-Type seal and shall remain in place with friction if not sealed

G2


H2




Telemetry




1022 Non-Functional - Metering - - - - 15.6 The nameplate shall include ANSI standard bar coding




1026 Functional - Metering - - - - 17.1 No equipment shall be shipped before all test and certification requirements are met


1028 Non-Functional - Metering - - - - 17.1 All tests shall be conducted using the same six test Meters


1030 Functional - Metering - - - - 17.1 ISO will approve the qualification of the facility and personnel who performs the testing

1031 Functional - Metering - - - - 17.1 ISO reserves the right to witness the tests






1037 Non-Functional - Metering - - - - 17.4 Test Setup: All tests shall be conducted at room temperature unless otherwise specified



1040 Non-Functional - Metering - - - - 17.5 Functional test (no load): The Meter shall be energized with no load




1044 Functional - Metering - - - - 17.6 Accuracy Test: Accuracy curves shall be provided for all combinations of the conditions



Filtered ventilation shall be provided in the base of the Meter to prevent condensation inside the Meter


The nameplate of the Meter shall include the Meter’s Serial Number and the Date of Manufacture. The manufacturing date shall include the year and month (i.e. 9601) or the Year and Week (i.e. 9644)


The nameplate shall have the following attributes: a) It shall be mounted on the front of the Meter; b) It shall not be attached to the removable meter cover; c) It shall be readable when the Meter is installed in the meter socket or Panel; d) It shall not impair access for accuracy adjustment or field replacement of components (such as the battery)



The nameplate shall include an easily erasable strip with minimum dimensions of 3/8 inch by 1-1/2 inches for penciling in items such as meter multiplier or the Meter Tester’s initials


The qualification testing is required for new Meter designs and for Meter product changes as defined in Section 6 of the Engineering Specification for Polyphase Meters (MTR 10-99)


The Supplier shall provide a certified test report documenting the tests and their results. The test report will be signed by the Supplier’s chief engineer and include all charts, graphs and data recorded during testing



Each test shall be conducted by the Supplier using a minimum of six Meters that are representative of production run meters



Meters which fail during the test shall not be repaired or tested further without the approval of the ISO




A Meter shall be designated as failed if: Failure of the Meter to meet the technical performance specifications included in the Specification


A Meter shall be designated as failed if: Signs of physical damage or performance degradation as a result of a test procedure, including effects, which could shorten the service life of the meter


A Meter shall be designated as failed if: The occurrence of an unexpected change of state, loss of data or other unacceptable mode of operation for the Meter as a consequence of a test procedure


A Meter design will be rejected if: When two or more Meters fail while performing the same test procedure


Test Setup: Before testing commences, the Meter shall be energized for a minimum of two hours at room temperature



Test Setup: The Meter shall be loaded to the nameplate test amperes at 100% power factor for all tests unless otherwise indicated


Test Setup: Full load test is 100% of the meter test amps, and light load test is 10% of the meter test amps



Functional test (no load): The Meter shall be programmed with ISO supplied parameters using a Meter Programmer


Functional test (no load): Operation of the specified functions will be verified over 24 hours by observing the meter display and by interrogating the contents of meter registers via a Meter Programmer


Functional test (no load): To pass this test the Meter shall operate as specified with no observed anomalies



To pass this test the Meter shall have the indicated accuracy at ambient temperature for the following load conditions: a) +/- 0.2% at Full load at power factor of 100%; b) +/- 0.25 % at Full load at power factor of 50% lag; c) +/- 0.25 % at Full load at power factor of 50% lead; d) +/- 0.25 % at Light load at power factor of 100%

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Telemetry





1058 Functional - Metering - - - - 18.1 Materials used in the construction of the Meter shall not create a fire hazard

1059 Business Rule - - - - - 10.2.6


Meter accelerated humidity cycling tests: a) The duration of the test shall be 24 hours; b) Condensation may form on the Meter during the test; c) Temperature shall be varied linearly during the tests at a constant rate not to exceed 20 C per hour; d) Humidity shall not be controlled during temperature changes


Meter accelerated humidity cycling tests: The test shall consist of the following sequence: a) Begin at +20 C (or room temperature if within 5 C); b) Ramp up to +85 C in approximately 3.25 hours; c) Ramp up to a relative humidity of 95% in approximately 1 hour; d) Hold at +85 C at a relative humidity of 95% +/- 1% for approximately 14.5 hours; e) Ramp down to +20 C in approximately 3.25 hours; f) Concurrently with step 'e' ramp down to a relative humidity of 75% in approximately 15 minutes; g) Hold relative humidity at 75% for remainder of temperature ramp down; h) Hold at 20 C at a relative humidity of 75% +/- 1% for approximately 2 hours


All accessible conductive parts on the exterior of the meter and conductive parts that are accessible upon removal of the meter cover shall be electrically connected to the Meter grounding tabs. All connections in the grounding circuit shall be made with an effective bonding technique


No materials that are toxic to life or harmful to the environment shall be exposed in the Meter during normal use




Scheduling Coordinators and other authorized users requiring Settlement Quality Meter Data for CAISO Metered Entities on whose behalf they Bid may obtain such data by accessing the CAISO’s Settlement Quality Meter Data Systems in accordance with the CAISO Tariff and applicable Business Practice Manuals.

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