ISO PROTOCOL AMENDMENTS
ANCILLARY SERVICES REQUIREMENTS PROTOCOL (ASRp)
ASRP 1	objectives, DEFINITIONS AND SCOPE
ASRP 1.1	Objectives
(a)	The ISO needs to have available to it sufficient Ancillary Services of a standard necessary to enable it to maintain the reliability of the ISO Control Area.
ASRP 2	Ancillary Services Standards
ASRP 2.1	Basis of Standards
ASRP 2.1.1	Basic criteria
(a)	The ISO shall base its Ancillary Services standards upon the Western System Coordinating Council (WSCC) Minimum Operating Reliability Criteria (MORC) and North American Electric Reliability Council (NERC) Criteria to the extent they are applicable to the ISO Control Area. 
ASRP 2.2	Review of Standards
ASRP 2.2.1	TAC Review
The ISO Technical Advisory Committee (TAC) shall periodically undertake a review of the ISO Control Area operations to determine any revision to the Ancillary Services standards to be used in the ISO Control Area.  As a minimum the ISO Technical Advisory Committee shall conduct such reviews to accommodate revisions to WSCC and NERC standards.
ASRP 4.5.3	Procurement as of Operations Date
Beginning January 1, 1998 the ISO will procure with the exception of ASRP 4.4.1 Regulation only from providers with Generating Units connected to and operating within the ISO Control Area.
ASRP 5.2	Standard for Non-Spinning Reserve: Quantity Needed
The required quantity of Non-Spinning Reserve shall be equal to the required quantity of Operating Reserve less the quantity of Spinning Reserve determined in ASRP 5.1 plus;
(a)	an amount of Non-Spinning Reserve equal to Interruptible Imports (which must be self provided by the Scheduling Coordinators responsible for the Interruptible Imports from resources within the ISO Control Area); and
(b)	an amount of Non-Spinning Reserve equal to on-demand obligations to other entities or Control Areas (which must be self provided by the Scheduling Coordinators responsible for the on-demand obligations from resources within the ISO Control Area).
Scheduling Coordinators may self provide their allocated quantity of Non-Spinning Reserve under ASRP 5.2(a) and (b) from Spinning Reserve not already committed to the ISO, if they wish.
ASRP 5.8.2	Procurement as of Operations Date
Beginning January 1, 1998 the ISO will procure Spinning and Non-Spinning Reserve only from providers connected and operating within the ISO Control Area.  
ASRP 6.1.2	Replacement Reserve Requirements
The ISO shall have discretion to determine the quantity of Replacement Reserve it requires in each Zone.  The ISO shall make its determination of the required quantity of Replacement Reserve based on: 
(f)	other factors influencing the ISO Control Area's ability to meet Applicable Reliability Criteria.
ASRP 6.5.2	Procurement as of Operations Date
Beginning January 1, 1998 the ISO will procure this Ancillary Service only from providers connected to and operating within the ISO Control Area.
ASRP 7	Voltage Support Standards
ASRP 7.1	Standard for Voltage Support: Quantity Needed
The ISO shall determine on a daily basis for each Settlement Period for each Trading Day the quantity and location of Voltage Support required to maintain voltage levels and reactive margins within WSCC and NERC criteria using a power flow study based on the quantity and location of Demand scheduled in each Settlement Period of the Day-Ahead Market.  The ISO shall issue daily voltage schedules (Dispatch instructions) to Generators, Participating TOs and UDCs for each Trading Day, which are required to be maintained for ISO Control Area reliability.

DEMAND FORECASTING PROTOCOL
DFP 1.1	Objectives
The objective of the DFP is to set forth procedures for submission of Demand Forecasts which will provide information to the ISO for projecting future Demand requirements to be served by the ISO Control Area.  The ISO shall utilize such forecasts to enable it to assess system reliability and carry out its functions under the Scheduling Protocol (SP) and the Outage Coordination Protocol (OCP).

DISPATCH PROTOCOL
DP 2.1	Applicable Reliability Criteria
The ISO shall exercise its authority as Control Area operator and its Operational Control over the ISO Controlled Grid in compliance with all Applicable Reliability Criteria.  Applicable Reliability Criteria are defined as the standards established by NERC, WSCC and Local Reliability Criteria and include the requirements of the Nuclear Regulatory Commission (NRC).
DP 2.2	Ancillary Services
The ISO will base its standards for the Dispatch of Ancillary Services upon WSCC MORC and ISO Control  Area reliability requirements.
DP 2.3	ISO Standards
The ISO Governing Board may establish guidelines more stringent than those established by NERC and WSCC as needed for the secure and reliable operation of the ISO Control Area.
DP 2.4	Good Utility Practice (Standards)
When the ISO is exercising its authority as ISO Control Area operator and its Operational Control of the ISO Controlled Grid, the ISO, Market Participants, EOEs and Non-Participating TOs which are parties to an Existing Control Agreement or an Existing Operating Agreement, shall comply with Good Utility Practice.  The ISO Tariff defines Good Utility Practice which, for ease of use of the DP, is repeated as follows:
DP 2.5	Existing Contracts
The ISO will implement Sections 2.4.3 and 2.4.4 of the ISO Tariff with respect to Existing Contracts after the close of the Hour-Ahead Market and in real time in accordance with this DP, the SBP and the SP.
DP 3.5	Information to be Supplied by UDCs, EOEs and Non-Participating TOs
DP 3.5.1	UDC Status Change
Each UDC, EOE and Non-Participating TO which is party to an Existing Control Agreement or an Existing Operating Agreement, shall keep the ISO informed of any change or potential change in the status of its lines and station equipment at the point of interconnection with the ISO Controlled Grid.  Each UDC, EOE and Non-Participating TO which is party to an Existing Control Agreement or an Existing Operating Agreement shall keep the ISO informed as to any event or circumstance in its service territory that could affect the reliability of the ISO Control Area.  This would include adverse weather conditions, fires, bomb threats, etc.
DP 3.5.2	UDC Outage Scheduling
Each UDC, EOE and Non-Participating TO which is party to an Existing Control Agreement or an Existing Operating Agreement, shall schedule all equipment Outages (or Outages of other equipment that could affect the ISO Control Area) at the point of interconnection with the ISO using the appropriate Outage scheduling procedures described in the OCP.
DP 3.5.3	UDC Outage Emergency Scheduling
Each UDC, EOE and Non-Participating TO which is party to an Existing Control Agreement or an Existing Operating Agreement, shall coordinate any requests for emergency Outages on point of interconnection equipment directly with the appropriate ISO Control Center as specified in DP 6.2.
DP 3.6.1	Transmission Status Change
Each PTO shall report any change or potential change in equipment status of the PTO’s transmission assets immediately to the ISO (this will include line and station equipment, line protection, Remedial Action Schemes and communication problems, etc.).  Each PTO shall also keep the ISO immediately informed as to any change or potential change in the PTO’s transmission system that could affect the reliability of the ISO Control Area.  This would include adverse weather conditions, fires, bomb threats, etc.
DP 3.7	Information to be supplied by generators
DP 3.7.1	Generator Status Change
Each Generator shall immediately inform the ISO, through its respective SC, of any change or potential change in the current status of any Generating Units that are under the Dispatch control of the ISO.  This will include, but not be limited to, any change in status of equipment that could affect the maximum output of a Generating Unit, the minimum load of a Generating Unit, the ability of a Generating Unit to operate with automatic voltage regulation, operation of the PSSs (whether in or out of service), the availability of a Generating Unit governor, or a Generating Unit’s ability to provide Ancillary Services as required.  Each Generator shall immediately report to the ISO, through its SC any actual or potential concerns or problems that it may have with respect to Generating Unit direct digital control equipment, Generating Unit voltage control equipment, or any other equipment that may impact the reliable operation of the ISO Control Area. 
DP 3.9	Information to be Supplied by an EOE or Non-Participating TO which is party to an Existing Control Agreement or  an Existing Operating Agreement
DP 3.9.1	Transmission Status Change
Each EOE, or Non-Participating TO which is party to an Existing Control Agreement or an Existing Operating Agreement, shall report any change or potential change in equipment status of its transmission assets immediately to the ISO (this will include line and station equipment, line protection, remedial action schemes and communication problems).  Each such entity shall also keep the ISO immediately informed as to any changes or potential changes in the its transmission system that could affect the reliability of the ISO Control Area.  This would include adverse weather conditions, fires, bomb threats, etc.
DP 3.9.2	Transmission Outage Scheduling
Each EOE, or Non-Participating TO which is party to an Existing Control Agreement or an Existing Operating Agreement, shall schedule all Outages of its lines and station equipment which could affect the reliability of the ISO Control Area in accordance with the appropriate procedure under the OCP.
DP 3.9.3	EOE Emergency Outage Scheduling
Each EOE, or Non-Participating TO which is party to an Existing Control Agreement or an Existing Operating Agreement, shall coordinate any request for or responses to Forced Outages on its transmission lines or station equipment which could affect the reliability of the ISO Control Area directly with the appropriate ISO Control Center as defined in DP 6.2.
DP 3.9.4	Generator Status Change
Each EOE, or Non-Participating TO which is party to an Existing Control Agreement or an Existing Operating Agreement, shall inform the ISO, through its respective SC, immediately of any change or potential change in the current status of any Generating Units that are under the Dispatch control of the ISO.  This will include, but not be limited to, any change in status of equipment that could affect the maximum output of a Generating Unit, the minimum load of a Generating Unit, the ability of a Generating Unit to operate with automatic voltage regulation, operation of the PSS (whether in or out of service), the availability of a Generating Unit governor, or a Generating Unit’s ability to provide Ancillary Services as required.  Each EOE, or Non-Participating TO which is party to an Existing Control Agreement or an Existing Operating Agreement, shall immediately report to the ISO, through its SC any trouble on Generating Unit direct digital control equipment, Generating Unit voltage control equipment, or any other equipment that may impact the reliable operation of the ISO Control Area.
DP 3.9.5	Generator or Interchange Schedule Change
Each EOE, or Non-Participating TO which is party to an Existing Control Agreement or an Existing Operating Agreement, shall inform the ISO, through its respective SC, of any change or potential change in the current status of all Generating Units, Interconnection schedules and Inter-Scheduling Coordinator Trades.  This will include any changes in Generating Unit capacity that could affect planned dispatch and conditions that could affect the reliability of a Generating Unit.  Each EOE, or Non-Participating TO which is party to an Existing Control Agreement or an Existing Operating Agreement, shall immediately pass to the ISO, through its respective SC, any information which it receives from a Generator which the Generator provides to it pursuant to DP 3.9.
DP 5.2.2	Communications during WEnet Unavailability
During any period of WEnet unavailability, the ISO shall:
(a)	make all reasonable efforts to keep Participants aware of current ISO Control Area status using voice communications;
DP 5.4.2	Backup ISO Control Center Response
The Backup ISO Control Center will post confirmation on the WEnet that all computer systems are functioning normally (if such is the case) and take complete control of the ISO Control Area.  The Backup ISO Control Center will notify the TOC by direct voice communication of the situation.
DP 5.7.2	Primary ISO Control Center Response
The Primary ISO Control Center will post confirmation on the WEnet that all computer systems are functioning normally (if such is the case) and take complete control of the ISO Control Area.  The Primary ISO Control Center will notify the SCE GCC by direct voice communications of the situation.
dP 6	Routine Operation of Transmission Facilities within the iso control area
DP 6.1	Overview/Responsibility
The ISO shall operate the ISO Control Area in accordance with the standards described in DP 2 and within the limit of all applicable nomograms and established operating limits and procedures.
DP 6.2	ISO Jurisdiction
DP 6.2.1	ISO Controlled Facilities
The ISO is the Control Area operator for the ISO Control Area, and shall direct the operation of all transmission lines and associated station equipment  under ISO jurisdiction as Control Area operator, including transmission facilities in the ISO Control Area which are the subject of Existing Control Agreements or Existing Operating Agreements.
DP 6.2.2	Primary ISO Control Center Jurisdiction
The Primary ISO Control Center shall have jurisdiction over:
(a)	all transmission lines greater than 230kV and associated station equipment under ISO jurisdiction as Control Area operator, including  transmission facilities in the ISO Control Area which are the subject of Existing Control Agreements or Existing Operating Agreements;
(b)	all Interconnections; 
(c)	all 230 kV and lower voltage transmission lines and associated station equipment identified in the ISO Register as that portion of the ISO Controlled Grid located in the PG&E Service Area; and
(d)	All 500 kV and lower voltage transmission lines and associated station equipment, which are the subject of Existing Control Agreements or Existing Operating Agreements in Service Areas within the ISO Control Area and in Service Areas contiguous to the Service Area of PG&E.
DP 6.2.3	Backup ISO Control Center Jurisdiction
The Backup ISO Control Center shall have jurisdiction over
(a)	all 230 kV and lower voltage transmission lines and associated station equipment identified in the ISO Register as that portion of the ISO Controlled Grid located in the SCE or SDGE Service Areas; and 
(b)	all 500 kV and lower voltage transmission lines and associated station equipment, which are the subject of Existing Control Agreements or Existing Operating Agreements in the Service Areas within the ISO Control Area and in service Areas contiguous to the Service Areas of SCE or SDGE.
DP 6.3	Clearing Equipment for Work
The clearance procedures of the ISO, the relevant UDC, PTO, EOE and Non-Participating TO which is a party to an Existing Control Agreement or an Existing Operating Agreement, must be adhered to by all parties, to ensure the safety of all personnel working on transmission lines and equipment in the ISO Control Area.  In accordance with the OCP, no work shall start on any equipment or line which is under the ISO jurisdiction as Control Area operator unless final approval has first been obtained from the appropriate ISO Control Center.  Prior to starting the switching to return any line or equipment to service the ISO shall confirm that all formal requests to work on the cleared line or equipment have been released.
DP 6.4	Equipment De-energized for Work
In some circumstances, System Reliability requirements may require a recall capability that can only be achieved by allowing work to proceed with the line or equipment de-energized only (i.e. not cleared and grounded).  Any personnel working on such de-energized lines and equipment must take all precautions as if the line or equipment were energized.  Prior to energizing any such lines or equipment deenergized for work, the ISO shall confirm that all formal requests to work on the de-energized line or equipment under its jurisdiction as ISO Control Area operator have been released.
DP 6.5	Hot-Line Work
The ISO has full authority to approve requests by PTOs, UDCs, EOEs and Non-Participating TOs who are parties to Existing Control Agreements or Existing Operating Agreements to work on energized equipment under ISO jurisdiction as Control Area operator, and no such work shall be commenced until the ISO has given its approval.
DP 6.6	Intertie Switching
The ISO and the appropriate single point of contact for the relevant PTO, UDC, EOE or Non-Participating TO which is party to an Existing Control Agreement or an Existing Operating Agreement and the adjacent Control Area shall coordinate during the de-energizing or energizing of any Interconnection.
DP 6.7	Operating Voltage Control Equipment
DP 6.7.1	Operating Voltage Control Equipment Under ISO Control
The ISO will direct the single point of contact for each PTO, EOE or Non-Participating TO which is party to an Existing Control Agreement or an Existing Operating Agreement in the operation of voltage control equipment that is under ISO jurisdiction as Control Area operator.
DP 6.7.2	Operating Voltage Control Equipment Under UDC Jurisdiction
Each UDC, EOE or Non-Participating TO which is party to an Existing Control Agreement or an Existing Operating Agreement must operate voltage control equipment under its control in accordance with its existing voltage control guidelines.
DP 6.7.3	Special ISO Voltage Control Requirements
The ISO may request a PTO, UDC, EOE or Non-Participating TO which is party to an Existing Control Agreement or an Existing Operating Agreement via its single point of contact to operate under special voltage control requirements from time to time due to special system conditions.
DP 6.8	Outages
The ISO will coordinate and approve Maintenance Outages and coordinate responses to Forced Outages of all transmission facilities under ISO jurisdiction as Control Area operator, including transmission facilities in the ISO Control Area which are the subject of Existing Control Agreements or Existing Operating Agreements, and Reliability Must-Run Units in accordance with the OCP.
DP 6.9.1	Security Coordinator
As Security Coordinator, the ISO may direct activities as appropriate to curtail Schedules, Dispatch Generation or impose transfer limitations as necessary to relieve Congestion, mitigate potential overloads or eliminate operation outside of established nomogram criteria.
DP 6.9.2	Authority of WSCC Security Coordinators
(a)	The Security Coordinator has the final authority to direct operations before, during and after problems or disturbances that have regional impacts.  The WSCC security monitoring plans include collaboration with sub-regional Security Coordinators and Control Area operators to determine actions for anticipated problems.  If there is insufficient time, or mutual concurrence is not reached, the Security Coordinator is authorized to direct actions and the Control Area operators must comply.
DP 7	Real Time Operational Activities – the Hour Prior to the Settlement Period
DP 7.1	Schedule Confirmation
In the hour prior to the beginning of the Settlement Period, the ISO will review and evaluate the current system operating conditions to ensure sufficient Energy and Ancillary Services resources are available for the next Settlement Period.  The ISO will:
(c)	verify that with currently anticipated operating conditions there is sufficient transfer capacity on the ISO Control Area to implement all Final Schedules.
DP 9.1.1	Range of ISO Authority
The ISO has full authority to:
(a)	direct the physical operation of the ISO Control Area, including (without limitation) circuit breakers, switches, voltage control equipment, protective relays, metering and Load Shedding equipment under ISO jurisdiction as Control Area operator, including facilities in the ISO Control Area which are the subject of Existing Control Agreements or Existing Operating Agreements;
DP 10.1.1	System alert
ISO will give a system alert notice when the operating requirements of the ISO Control Area are marginal because of Demand exceeding forecast, loss of major Generation or loss of transmission capacity that has curtailed imports into the ISO Control Area, or if the Hour-Ahead Market is short on scheduled Energy and Ancillary Services for the ISO Control Area.
DP 10.1.2	System warning
The ISO will give a system warning notice when the operating requirements for the ISO Control Area are not being met in the Hour-Ahead Market, or the quantity of Regulation, Spinning Reserve, Non-Spinning Reserve, Replacement Reserve and Supplemental Energy available to the ISO is not acceptable for the Applicable Reliability Criteria.
DP 10.1.3	System Emergency
When, in the judgement of the ISO, the System Reliability of the ISO Control Area is in danger of instability, voltage collapse or under-frequency caused by transmission or Generation trouble in the ISO Control Area, or events outside of the ISO Control Area that could result in a cascade of events throughout the WSCC grid, the ISO will declare a System Emergency.  This declaration may include a notice to suspend the Day-Ahead, Hour-Ahead and Real Time Markets, authorize full use of Black Start Generation, initiate full control of manual Load Shedding, authorize the curtailment of Curtailable Demand (even though not scheduled as an Ancillary Service).  The ISO will reduce the System Emergency declaration to a lower alert status when it is satisfied, after conferring with Security Coordinators within the WSCC that the major contributing factors have been corrected, all involuntarily interrupted Demand is back in service (except interrupted Curtailable Demand selected as an Ancillary Service).  This reduction in alert status will reinstate the competitive markets if they have been suspended.
DP 10.2.2	Emergency Procedures
In the event of a System Emergency, the ISO shall:
(a)	take action as it considers necessary to preserve or restore stable operation of the ISO Control Area;
DP 10.2.3	Intervention in Market Operations
(b)	The ISO will not intervene in the operation of the Day-Ahead Market unless there has been a total or major collapse of the ISO Control Area and the ISO is in the process of restoring it.
DP 10.2.8	Obligations of Participating Generators Relating to System Emergencies
All Generating Units are subject to control by the ISO during a System Emergency.  The ISO shall have the authority to:
(c)	instruct the alteration of scheduled deliveries of Energy and/or Ancillary Services into or out of the ISO Control Area,
if such an instruction is reasonably necessary to prevent an imminent System Emergency or to aid in restoring normal operation of the ISO Control Area during an actual System Emergency, and provided that the ISO has, where reasonably practicable, utilized Ancillary Services which it has the contractual right to instruct and which are capable of contributing to or containing or correcting actual, imminent or threatened System Emergencies prior to issuing such instructions.
DP 10.3	External Support/Assistance
If, on a real time basis, the ISO is unable to comply with the Applicable Reliability Criteria, the ISO shall take such steps as it considers necessary, to ensure compliance, including the negotiation of contracts for Ancillary Services through processes other than competitive solicitations.  If the ISO is unable to obtain such resources from within the ISO Control Area, the ISO may solicit Ancillary Services from other Control Areas on a real time basis.
DP 10.4.1	Use of UDC’s Existing Load Curtailment Programs.
(a)	UDC Electrical Emergency Plans
The ISO shall have the authority to implement a UDC’s Electrical Emergency Plan in consultation with the UDC, when Energy reserve margins are forecast to be at the levels specified in the existing plan.
(b)	UDC Under-Frequency Load Shedding Programs (UFLS):
The ISO shall:
(i)	with the UDC, review that UDC’s UFLS program periodically to ensure compliance with Applicable Reliability Criteria;
(ii)	perform periodic audits of each UDC’s UFLS to verify that the system is properly configured for each UDC; and
(iii)	use reasonable endeavors to ensure that the total ISO UFLS is coordinated among the UDCs so that no UDC bears a disproportionate share of the total ISO UFLS program.
(c)	UDC Disconnect Load
The ISO shall have the authority to direct a UDC to disconnect Load from the ISO Controlled Grid if necessary to avoid an anticipated System Emergency or to aid in restoring normal operation of the ISO Control Area during an actual System Emergency.
DP 12		Information Management
The ISO shall provide all Participants with non-discriminatory access to information concerning the status of the ISO Control Area by posting such information on the WEnet, or other similar computer communications device, or by telephone or facsimile in the event of computer systems failure.

MP Appendix D
STANDARDS FOR METERING FACILITIES
Exhibit 1 to Appendix D
Specification MTR 1-96
Engineering Specification for Polyphase Solid-State
 Electricity Revenue Quality Meters 
for use on the ISO Controlled Grid
10.7	Clock
Clocks shall meet the following requirements:
(a)	the clock internal to the Meter shall be accurate within 2 minutes per week (0.02%) when not synchronized to the operation line frequency and shall be resettable through the ISO communications interface.  The ISO will transmit a periodic master synchronizing signal to the meter;
(b)	the internal clock shall have two modes of operation as follows:
i.	the clock shall synchronize with the operation 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; and

OUTAGE COORDINATION PROTOCOL (OCP)
OCP 3	PLANNING OF ISO CONTROLLED GRID MAINTENANCE
OCP 3.1	Data to ISO
All information submitted in relation to planned Outages of facilities under ISO jurisdiction as Control Area operator, including transmission facilities in the ISO Control Area which are the subject of Existing Control Agreements or Existing Operating Agreements must be submitted in accordance with OCP 7.
OCP 3.1.6	Adjacent Control Areas
The ISO will coordinate the exchange of proposed Maintenance Outages of facilities under ISO jurisdiction as Control Area operator, including transmission facilities in the ISO Control Area which are the subject of Existing Control Agreements or Existing Operating Agreements, as appropriate, with the operators of adjacent Control Areas.
OCP 3.2	ISO Analysis of Outage Plans
OCP 3.2.1	Review of Planned Maintenance Outages
The ISO Outage Coordination Office will review the Maintenance Outages submitted under OCP 2.2 and OCP 3.1 to determine if any one or a combination of Maintenance Outage requests relating to facilities under ISO jurisdiction as Control Area operator, including transmission facilities in the ISO Control Area which are the subject of Existing Control Agreements or Existing Operating Agreements, or Reliability Must-Run Units may cause the ISO to violate the Applicable Reliability Criteria.  This review will take consideration of factors such as, but not limited to, the following:
OCP 5	Maintenance Scheduling and Approval
OCP 5.2	Adjacent Control Areas
The ISO will coordinate the scheduling of maintenance of facilities under ISO jurisdiction as Control Area operator, including transmission facilities in the ISO Control Area which are the subject of Existing Control Agreements or Existing Operating Agreements, and approvals, as necessary, with the operators of adjacent Control Areas .
OCP 5.3.1	Three (3) Day Prior Notification
Any request to confirm an Approved Maintenance Outage that may affect the transfer capability of any part of the facilities under ISO jurisdiction as Control Area operator, including other transmission facilities in the ISO Control Area which are the subject of Existing Control Agreements or Existing Operating Agreements, must be submitted no later than 11:30 am at least three (3) working days prior to the starting date of the Approved Maintenance Outage.  OCP 5.3.1 applies to:
(h)	any other Outage that the ISO reasonably considers will affect the transfer capability of a line or path compromising any part of the ISO Controlled Grid or other transmission facilities in the ISO Control Area which are the subject of an Existing Control Agreement or Existing Operating Agreement.
OCP 5.9	Withholding of Final Approval and Rescheduling of Outage
The ISO Control Center shall have the authority to withhold a Final Approval for reasons of System Reliability, security or system status of facilities under ISO jurisdiction as Control Area operator, including transmission facilities in the ISO Control Area which are the subject of Existing Control Agreements or Existing Operating Agreements.  The ISO Control Center shall immediately notify the relevant Participating TO of its intention to withhold the Final Approval.  The ISO Grid facility Maintenance Outage will then be rescheduled pursuant to the Dispatch Protocol.
OCP 8	Outage Coordination for New Facilities
OCP 8.1	Coordination by ISO
The procedure to energize and place in service any new or relocated piece of equipment, connected to the facilities under ISO jurisdiction as Control Area operator, including transmission facilities in the ISO Control Area which are the subject of Existing Control Agreements or Existing Operating Agreements, must be set out by the relevant Participating TO, Non-Participating TO, EOE, Participating Generator or Connected Entity in a written procedure and coordinated by the ISO Outage Coordination Office.
OCP 8.2	Types of Work Requiring Coordination
The types of work which the ISO will coordinate under OCP 8 includes any new addition, replacement or modification to the facilities under ISO jurisdiction as Control Area operator, including transmission facilities in the ISO Control Area which are the subject of Existing Control Agreements or Existing Operating Agreements, including:

SCHEDULES AND BIDS PROTOCOL (SBP)
SBP 2.1.3	External Import/Export Section of a Balanced Schedule and Adjustment Bid Data
The external import/export section of a Balanced Schedule will include the following information for each import or export:
(o)	hourly scheduled external imports/exports in MWh (the ISO will multiply these values by the hourly Generation Meter Multipliers), including any zero values, for each Settlement Period of the Trading Day (in the case of a Day-Ahead Schedule) and for the relevant Settlement Period (in the case of an Hour-Ahead Schedule) and with external imports into the ISO Control Area reported as negative quantities and external exports from the ISO Control Area reported as positive quantities; and

Scheduling Coordinator application protocol (SCAP)
SCAP 1.2.2	Special Terms for this Protocol
In this Protocol, the following words and expressions shall have the meaning set forth below:
“SC Customer” means a customer of the SC Applicant or a Scheduling Coordinator for whom the SC provides services relevant to the ISO Control Area.
SCAP 7.2	ISO’s Response for Failure to Inform
SCAP 7.2.1	Failure to promptly Report a Material Change
If an SC fails to inform the ISO of a material change in its information provided to the ISO, which may affect the reliability or safety of the ISO Control Area, or the financial security of the ISO, the ISO may suspend or terminate the SC’s rights under the ISO Tariff in accordance with the terms of ISO Tariff Sections 2.2.7.3 and 2.2.4 respectively.  If the ISO intends to terminate the SC’s rights it shall file a Notice of Termination with FERC.  Such termination shall be effective upon acceptance by FERC of a Notice of Termination.

SCAP APPENDIX A
SCHEDULING COORDINATOR APPLICATION FORM
4.2	For Loads and Generating Units located within the ISO Control Area, does the SC Applicant have any scheduling restrictions imposed by the parties they represent?  (yes / no)    If yes, provide full details on a separate sheet of paper.
V.	Third Party Contractual Requirements
5.1	The SC Applicant confirms that all of its SC Customers which are located within the ISO Control Area and which should execute agreements with the ISO have entered into or will enter into, prior to the certification of the SC Applicant, all required agreements with the ISO to enable them to meet the requirements of the ISO Tariff:   	  (yes / no).  

SCHEDULING PROTOCOL (SP)
SP 1	OBJECTIVES, DEFINITIONS AND SCOPE
SP 1.1	Objectives
The objectives of this Protocol are:
(a)	to process the scheduling input data (submitted to the ISO under the Ancillary Service Requirements Protocol (ASRP), the Demand Forecasting Protocol (DFP), and the Schedules and Bids Protocol (SBP)) in order to develop Final Schedules for the Day-Ahead and Hour-Ahead Markets (real time management of the ISO Control Area is addressed in the Dispatch Protocol (DP));
SP 3.1.6	Final Schedules
If the ISO notifies a SC that there will be no Congestion in the ISO Control Area based on the Preferred Schedules submitted by all SCs, the Preferred Schedule shall become that SC’s Final Schedule.  If the ISO notifies a SC that there will be no Congestion in the ISO Control Area based on the Revised Schedules submitted by all SCs, the Revised Schedule shall become that SC’s Final Schedule.  If there is Congestion based on the Revised Schedules, the ISO shall modify the Revised Schedules and issue Final Schedules.  The SCs will be notified, via WEnet, that their Schedules have become final.  The ISO will also publish a final set of Usage Charges for Energy transfers between Zones, applicable to all SCs.
SP 3.2.1	By 6:00 pm, Two Days Ahead
By 6:00 pm two days ahead of the Trading Day (for example, by 6:00 pm on Monday for the Wednesday Trading Day), the ISO will publish, via WEnet, the following information for each Settlement Period of the Trading Day:
(a)	a forecast of conditions within the ISO Control Area, including transmission line and other transmission facility Outages;
SP 4	Transmission System Loss Management
SP 4.1	Overview
(a)	A SC must ensure that each Schedule it submits to the ISO is a Balanced Schedule in which aggregate Generation and external imports (adjusted for Transmission Losses) and Inter-Scheduling Coordinator Trades equals the aggregate Forecast Demand and external exports.  The ISO will, for this purpose, specify GMMs for each Energy supply source (Generating Units and external imports at Scheduling Points) to account for the Energy lost in transmitting power from Generating Units and/or Scheduling Points to Load.  Inter-Scheduling Coordinator Trades will not be subject to such adjustments, beyond the impact of GMMs on the respective SC’s Generation and external imports.  The ISO will, in accordance with this SP 4, derive a location specific GMM for each Generating Unit and external import in the ISO Control Area.
SP 5	Reliability Must-Run Generation
SP 5.1	Procurement of Reliability Must-Run Generation by the ISO
SP 5.1.1	Annual Reliability Must-Run Forecast - Technical Evaluation
On an annual basis, the ISO will carry out technical evaluations based upon historic patterns of the operation of the ISO Control Area and the ISO's forecast requirements for maintaining the reliability of the ISO Control Area in the next year.  The ISO will then determine which Generating Units it requires to continue to be Reliability Must-Run Units, which Generating Units it no longer requires to be Reliability Must-Run Units and which Generating Units it requires to become the subject of a Reliability Must-Run Contract which had not previously been so contracted to the ISO.  None of the Generating Units owned by Local Publicly Owned Electric Utilities are planned to be designated as Reliability Must-Run Units by the ISO as of the ISO Operations Date but are expected to be operated in such a way as to maintain the safe and reliable operation of the interconnected transmission system comprising the ISO Control Area.  However, in the future, Local Publicly Owned Electric Utilities may contract with the ISO to provide Reliability Must-Run Generation.
SP 5.2	Designation of Generating Unit as Reliability Must-Run
The ISO will have the right at any time based upon ISO Control Area technical analyses and studies to designate or disqualify a Generating Unit as a Reliability Must-Run Unit.
SP 7.5	The ISO’s Real-Time Process
Consistent with SP 7.4.4, the ISO will honor those scheduling flexibilities that may be exercised by holders of Existing Rights and Non-Converted Rights through their respective SCs during the ISO’s real-time processes to the extent that such flexibilities do not interfere with or jeopardize the safe and reliable operation of the ISO Control Area or Control Area operations.  The real-time processes described in SP 7.5.1 and SP 7.5.2 will occur during the three hours following the ISO’s receipt of Preferred Hour-Ahead Schedules (that is, from two hours ahead of the start of the Settlement Period through the end of such Settlement Period).
SP 9	Day/Hour-Ahead Ancillary Services Management
SP 9.1	Bid Evaluation and Scheduling Principles
The ISO will evaluate Ancillary Services bids based on the following principles:
(a)	the ISO will not differentiate between bidders other than through reserve (Regulation and Operating Reserves) price and capability to provide the reserve service, and the required locational mix of services;
(b)	to minimize the costs to users of the ISO Control Area, the ISO will select the bidders with lowest bids for reserve which meet its technical requirements, including location and operating capability;

SETTLEMENT AND BILLING PROTOCOL (sabp)
APPENDICES A–i
SABP Appendix A
GRID MANAGEMENT CHARGE COMPUTATION
A 3.2	QChargej -- MWh
The monthly metered consumption (including Wheeling Out and Wheeling Through the ISO Controlled Grid or the ISO Control Area) for the Scheduling Coordinator whose Grid Management Charge is being calculated.
SABP Appendix C
ANCILLARY SERVICES CHARGES COMPUTATION
C 1	Purpose of charges
The Ancillary Services Charges reimburse the ISO for the costs of purchasing Ancillary Services in the Day-Ahead and Hour-Ahead Markets.  Each Scheduling Coordinator that does not self provide Ancillary Services must purchase these services from the ISO.  The ISO will in turn purchase these Ancillary Services from Scheduling Coordinators in the markets.  Ancillary Services purchased and resold by the ISO includes Regulation, Spinning Reserve, Non-Spinning Reserve, and Replacement Reserve.
This Appendix C also addresses the payments by ISO to Scheduling Coordinators for the Dispatch of energy from Dispatched Ancillary Services Units and for the Dispatch of Supplemental Energy in the Real Time Market.  The ISO recovers the costs of Real Time Dispatch of such energy through the Imbalance Energy charges described in Appendix D of this Protocol.
The reference to a Scheduling Coordinator by Zone refers to the Demand of that Scheduling Coordinator which is located in the Zone.  A Generation Unit, Load, or System Resource located in another Control Area is considered to be located in the Zone in which its contract path enters the ISO Control Area.

Exhibit B
Notice Suitable for Publication in the Federal Register
Pacific Gas and Electric Company, San Diego Gas & Electric Company and Southern California Edison Company	Docket Nos. 
EC96-19-___ and 
ER96-1663-_____	

NOTICE OF FILING
Take notice that on February 25, 1998, the California Independent System Operator Corporation filed for Commission acceptance in this docket, pursuant to Section 205 of the Federal Power Act, an application to amend the ISO Tariff, including the ISO Protocols, and a motion for waiver of the 60-day notice requirement.  The ISO requests that the proposed amendments be made effective as of the ISO Operations Date.

The ISO states that the proposed amendments, which would create a new definition for the “ISO Control Area,” distinct from the “ISO Controlled Grid and from any other “Control Area,” are necessary for the initial operations of the ISO.

Any person desiring to be heard or to protest said filing should file a petition to intervene or protest with the Federal Energy Regulatory Commission, 888 First Street, N.E., Washington, D.C., 20426, in accordance with 18 C.F.R. §§ 385.212 and 385.207.  All such petitions or protests should be filed on or before _________.  Protests will be considered by the Commission in determining the appropriate action to be take, but will not serve to make Protestants parties to the proceeding.  Any person wishing to become a party must file a petition to intervene.  Copies of this application are on file with the Commission and available for public inspection.