ࡱ>    ibjbjޥ ǴǴH M^/^/<4<(===>>>?B|>K@@NPPPSbXdvYFHHHHHH$kl=/\pS@S/\/\l==PPTnnn/\=P=Pbn/\Fnn.4FP"|=G\|&\N03cFF=Z*ZZZ@nZ4Z7*Z*Z*Zllh*Z*Z*Z/\/\/\/\*Z*Z*Z*Z*Z*Z*Z*Z*Z^/ ~;:  app Manual for the Forward Capacity Market (FCM) Manual M-20 Revision: 22 Effective Date: December 31, 2015 Prepared by app. app Manual for the Forward Capacity Market (FCM) Table of Contents Introduction About This Manual INT-1 Section 1: Master Forward Capacity Auction Schedule Section 2: Market Participant Action Matrices 2.1 Resource Qualificaiton 2-1 2.2 Forward Capacity Auction 2-38 2.3 Critical Path Monitoring 2-44 2.4 Reconfiguration Auction 2-47 2.5 Bilateral Contracts 2-52 2.6 Rights and Obligations 2-68 2.7 Performance, Payments and Charges 2-77 Section 3: Requirements Applicable to Dispatchable Asset Related Demands 3.1 Establishing and Adjusting Dispatchable Asset Related Demand Coincident Peak Contribution 3-1 3.1.1 Adjustments to Dispatchable Asset Related Demand Coincident Peak Contribution 3-1 3.1.1.1 Dispatchable Asset Related Demand Non-Conforming Demand Bid Adjustment 3-2 3.1.1.2 Dispatchable Asset Related Demand Metering Adjustment 3-2 Attachments A to B: Reserved Attachment C: Host Participant Assigned Meter Reader Requirements Attachments D to H: Reserved Attachment I: Northeast MOU General ICAP Principles Attachment J: Reserved Attachment K: Maintenance Allotment Hours Attachment L: Reserved Attachment M: New Import Capacity Resource Qualification Information Form Revision History Approval REV-1 Revision History REV-1 Introduction Welcome to the app Manual for the Forward Capacity Market. In this introduction, you will find the following information: What you can expect from this app Manual (see About This Manual). How to use this Manual (see Using This Manual). About This Manual The app Manual for the Forward Capacity Market is one of a series of manuals within the app set of manuals. This manual focuses on the procedures for the Forward Capacity Market (FCM) administered by the app pursuant to Section III.13 of Market Rule 1. This manual is designed as a reference guide to provide Market Participants participating in the FCM with additional information or details regarding steps or actions they must take as set forth in Section III.13 or Appendix A of Market Rule 1 that pertain to the FCM. A copy of Market Rule 1 and the Tariff may be obtained from the app website at HYPERLINK "http://www.iso-ne.com"www.iso-ne.com. This manual was written assuming that the reader has read Market Rule 1 before or in conjunction with using this manual. Terms that are capitalized in this manual shall have the meaning ascribed to them in Market Rule 1 or the Tariff. The reader is referred first to Market Rule 1 for an explanation and information regarding each aspect of the operation of the FCM or requirements for complying with the FCM rules. This manual provides additional implementation or other detail for those provisions of Market Rule 1 which require the Market Participant to take an action. Manual provisions are developed and refined through the NEPOOL stakeholder processes. Manuals are not filed with or approved by the Federal Energy Regulatory Commission. In the event of any conflict between a Market Rule 1 provision and this manual, the text of the Market Rule 1 provision governs. This manual is organized as a set of matrices. The Market Participant Action Matrices identify for each provision of Market Rule 1 the resource type(s) to which the provision applies and, where the provision requires an action by the Market Participant, a statement of the action and information regarding the app process or system to be used by the Market Participant to complete that action. There is a separate Market Participant Action Matrix for each major section/subsection of Market Rule 1. The format of the Market Participant Action Matrix and a key explaining the matrix are provided below. Market Participant Action Matrix Sample and Key The Market Participant Action Matrix in the following format. ABCDEFResource TypeMaster Schedule Step/ Event IdentifierMarket Rule 1 III Section NumberParticipant ActionDescription of Participant Deliverables/ Additional InformationSystem and/or ProcessD RG CI CI PXXXXA2313.1Complete Participant Membership Process Complete and mail all of the following to the app membership coordinator: HYPERLINK "http://www.iso-ne.com/support/reg_info/membership/membership_application_package.doc"Membership application [DOC] HYPERLINK "http://www.iso-ne.com/support/reg_info/membership/participant_application_fees.pdf"Application fee [PDF] HYPERLINK "/forms/formLoad.action?formId=2"New Member Credit Application HYPERLINK "http://www.iso-ne.com/stlmnts/assur_crdt/newapp_docs/credit_app_checklist.doc"Additional financial assurance requirements [DOC] HYPERLINK "http://www.iso-ne.com/support/custsvc/forms/iso_new_england_security_administrator_signatory_page.pdf"Security Administrator Signatory Page [PDF] HYPERLINK "http://www.iso-ne.com/stlmnts/assur_crdt/newapp_docs/index.html"Completed W-9 or W-8, as applicable For information on how to submit participant membership applications and other materials, see the apps website, Registration Information - HYPERLINK "http://www.iso-ne.com/support/reg_info/index.html"http://www.iso-ne.com/support/reg_info/index.html.  The following table provides further detail and explanation regarding the manual matrix. Market Participant Action Matrix KeyColumnExplanationAResource Type. These columns identify the resource type to which each Market Rule 1 provision applies (reflected by an X). The resource types are identified below. Matrix AbbreviationResource Type as defined in Market Rule 1DRReal-Time Demand Response ResourceDRReal-Time Emergency Generation Resource DROn-Peak Demand ResourceDRSeasonal Peak Demand ResourceGCGenerating Capacity ResourceICImport Capacity ResourceIPIntermittent Power ResourceIPIntermittent Settlement Only ResourceBMaster Schedule Step/Event Identifier. This column permits the reader to cross reference the Market Rule 1 provision with the applicable timetable or process schedule defined in Market Rule 1 and/or developed by the app for implementation of each particular aspect of Market Rule 1. The steps and events are included in Section 1 of this manual. CMarket Rule 1 Section Number. This column identifies by provision number and title the Market Rule 1 provision at issue and serves as an indexing function for the reader. DParticipant Action. This column defines the action that each provision of Market Rule 1 requires a Market Participant to take. Entries are provided for those provisions requiring or permitting a Market Participant action. The user must refer to the Market Rule 1 provision as stated in the Tariff for a complete statement of the required or permitted action and the eligibility of the Market Participant to take that action, as well as any precursor steps that may be required. If no entry appears in this column for a provision, the app has determined that the provision does not describe a required or permitted Market Participant action. EDescription of Participant Deliverables/Additional Information. This column provides additional implementation detail regarding the deliverable that the Market Rule 1 provision requires or permits the Market Participant to provide. If no entry is made in this column for a provision, Market Rule 1 provides sufficient detail to enable the Market Participant to determine the form and format of the Market Participant deliverable(s) and action(s). FSystem and/or Process. This column identifies the app system or process (as applicable) that the Market Participant must use to complete the required or permitted actions or submit the required deliverables.  Market Participants are encouraged to take advantage of the numerous training opportunities available to advance their understanding of Market Rule 1 and the actions undertaken to participate in the New England Markets, including the FCM. A variety of classroom courses and web conferences are offered on a regular schedule, and all recent training presentations are posted on the app website. In addition, participants may view at their convenience numerous recorded web conferences and web-based training tutorials that are posted on the app website as well. For a complete list of the current offerings, please consult the Market Training page on the app website. Section 1: Master Forward Capacity Auction Schedule All Forward Capacity Market deadlines can be found on the app website on the FCM page by searching for FCM Auction Calendars under Document Type and in the Forward Capacity Tracking System (FCTS) in the FCM calendar tab. All Market Participants and non-Market Participants can request access to FCTS by e-mailing the Forward Capacity Market Non-Market Participant Registration Request form to  HYPERLINK "mailto:custserv@iso-ne.com" custserv@iso-ne.com. Master FCA ScheduleMR X-ReferenceStep/Event IdentifierStep/EventA1Capacity Commitment Period (Start Date)13.1.10A2Show of Interest (Start)13.1.10A3Show of Interest (End)A4(Reserved)A5(Reserved)13.1.2.3 13.1.4.2.5.2A6app Notifies Existing Capacity of Qualified MWs (QCN)13.1.4.6.1A7app Publishes Dispatch Zones(Reserved)13.1.2.2.5A9Significant Increase Request Due13.1.2.3A10Existing Capacity Challenge Window Closes13.1.1.1.6 13.1.2.3.1A11Reactivation Plans Due13.1.4.3A12Existing DR updated Measurement &Verification (M&V) Plans13.1.2.3A13app Notifies Capacity of Challenge Outcome13.1.2.2.4A14Significant Decrease Election Date13.1.10 13.1.4.2.1A15Existing Capacity Qualification Deadline13.1.2.3.1A16Submission of Static De-List Bid, Permanent De-List Bid13.1.8A17app Posts Existing Capacity Static De-List Bid, Permanent De-List Bid and Export Bid Information13.1.10 13.1.4.2.2A18New Capacity Qualification Deadline (Critical Path)13.1.3.5.1 13.1.3.5.3.1A19New Import Capacity Documentation DueA20(Reserved)13.1.8A21app Posts New Import Capacity Offer Information13.1.1.2.1A22Show of Interest (SOI) Reduction in Capacity Changes Deadline for Generation13.1A23Market Participant Status Deadline13.1.2.4 13.1.1.2.8 13.1.4.2.5A24app Notifies New Capacity of Qualification Acceptance/Denial and Disposition of De-List Requests for New and Existing (QDN)13.1.2.3.2.1.1.2A24.1Static De-List Bids Finalization Period13.1.8A25app Posts Internal Market Monitor approved Static and Permanent De-List Bid Information13.1.2.3.1.5A26Non-Price Retirement Request Window Closes13.1.5A27Composite Offer Deadline13.1.5.AA28Notification of FCA Qualified Capacity13.1.1.2A29Sponsor Withdrawal Deadline from Qualification ProcessA30Collect Financial Assurance Information from Accepted New Capacity (Section VII of the Financial Assurance Policy--Exhibit IA to Section I of the Tariff)13.1.6A31Self Supply Designation Deadline for Generation13.8.1A32FERC Informational Filing Due13.1.4.2.2.4.2A33DR Milestones13.1.4.2.2.4.3A34Pipeline Analysis Submittal13.2.1A35Conduct FCA (beginning date)13.1.4.3.1.3A36DR M&V Annual Certification Section 2: Market Participant Action Matrices 2.1 Resource Qualification #Resource TypeMaster Schedule Step/ Event IdentifierMarket Rule 1 III Section Number (13.1.1)Participant ActionDescription of Participant Deliverables/Additional Informationapp System and/or ProcessD RG CI CI P1XXXXA2313.1Submit application to become Market Participant.For information on how to become a Market Participant, see the apps website, Registration Information - HYPERLINK "http://www.iso-ne.com/support/reg_info/index.html"http://www.iso-ne.com/support/reg_info/index.html.2XXX13.1.1.2Submit one or more Interconnection Requests prior to submitting a New Capacity Show of Interest Form during the New Capacity Show of Interest Submission Window.To view documentation go to: HYPERLINK "http://www.iso-ne.com/genrtion_resrcs/nwgen_inter/index.html"http://www.iso-ne.com/genrtion_resrcs/nwgen_inter/index.html  3XXXXA29 13.1.1.2Withdraw a New Generating Capacity Resource from the qualification process. Contact app Customer Support for additional information.4XXXXA313.1.1.2.1Submit New Capacity Show of Interest Form during New Capacity Show of Interest Submission Window. The New Capacity Show of Interest Form is submitted using the Forward Capacity Tracking System (FCTS) user interface.5XXXXA2213.1.1.2.1Amend the New Capacity Show of Interest Form after it has been submitted.Changes to the New Capacity Show of Interest Form not prohibited by this provision are done using the Forward Capacity Tracking System (FCTS) user interface.6XXXXA1813.1.1.2.1(a)Submit information necessary to evaluate a project with the New Capacity Show of Interest Form to the extent the information is not already provided under an active Interconnection Request. This information is submitted using the Forward Capacity Tracking System (FCTS) user interface. 7XXXA1813.1.1.2.1(b)Submit with the New Capacity Show of Interest Form documentation demonstrating that the Project Sponsor has already achieved control of the project site for the duration of the relevant Capacity Commitment Period. This information is submitted using the Forward Capacity Tracking System (FCTS) user interface. 8XXXXA1813.1.1.2.2Submit a New Capacity Qualification Package.The New Capacity Qualification Package is submitted using the Forward Capacity Tracking System (FCTS) user interface.9XXXA1813.1.1.2.2.1Submit with the New Capacity Show of Interest Form documentation demonstrating that the Project Sponsor has already achieved control of the project site for the duration of the relevant Capacity Commitment Period.Site control information is submitted using the Forward Capacity Tracking System (FCTS) user interface. 10XXXA1813.1.1.2.2.2Submit with the New Capacity Qualification Package a critical path schedule.Critical path schedule information is submitted using the Forward Capacity Tracking System (FCTS) user interface. 11XXXA1813.1.1.2.2.3(a)Submit supporting documentation related to potential offers below the relevant Offer Review Trigger Price.Information about offering below the relevant Offer Review Trigger Price is submitted using the Forward Capacity Tracking System (FCTS) user interface.12XXXA1813.1.1.2.2.3(b)Elect in the New Capacity Qualification Package if the eligible offer may be rationed, including a quantity at or above which the offers may be rationed, as applicable.This election is made by using the Forward Capacity Tracking System (FCTS) user interface. 13XXXA1813.1.1.2.2.4Elect multiple Capacity Commitment Period treatment for eligible New Capacity Resources.This election is made by using the Forward Capacity Tracking System (FCTS) user interface.14XXA1813.1.1.2.2.5(a)Submit with the New Capacity Qualification Package for resources qualifying pursuant to Section III.13.1.1.1.2 (re-powering), Section III.13.1.1.1.3 (incremental capacity), or Section III.13.1.1.1.4 (de-rated capacity) documentation of the costs associated with the project in sufficient detail to allow the app to determine that the relevant cost thresholds described in Sections III.13.1.1.1.2(b), III.13.1.1.1.3(b), and III.13.1.1.1.4) will be met.This information is submitted using the Forward Capacity Tracking System (FCTS) user interface. 15XXA1813.1.1.2.2.5(b)Submit with the New Capacity Qualification Package for resources qualifying pursuant to Section III.13.1.1.1.2(c) (environmental compliance) Submit a detailed description of (i) the applicable regulations and the permits, and (ii) documentation of the costs associated with the project in sufficient detail to allow the app to determine that the relevant cost threshold (described in Section III.13.1.1.1.2(c)) will be met.This information is submitted using the Forward Capacity Tracking System (FCTS) user interface. 16XXA1813.1.1.2.2.5(c)Submit with the New Capacity Qualification Package pursuant to Sections III.13.1.1.1.2, III.13.1.1.1.3, or III.13.1.1.1.4.Submit detailed information showing how and when the resource will shed any existing Capacity Supply Obligation to accommodate any necessary intervening (i.e., repowering) work on the facility.17XXA1813.1.1.2.2.6(b)Submit with the New Capacity Qualification Package measured and recorded site specific summer and winter data relevant to the expected performance of the resource that will enable the app to confirm [the claimed] summer and winter Qualified Capacity.This information is submitted using the Forward Capacity Tracking System (FCTS) user interface. 18XXA1813.1.1.2.2.3 A.21.2For New Capacity Resources requesting to submit offers below the relevant Offer Review Trigger Price, submit with the New Capacity Qualification Package sufficient documentation and information to permit the Internal Market Monitor to perform its review. Recommended documents include but not limited to the following: Project capital costs by components (e.g. turbine, SCR, gas compressor, construction, engineering & procurement, development & permitting, etc.) Capital structure, i.e. percentage debt versus equity, investment horizon, estimated cost of debt, after tax return on equity, etc. A 20-year heat rate estimate for the project (Btu/kWh). A 20-year forecast of expected capacity factor (%). A 20-year forecast of expected generation (GWh/year). A 20-year forecast of expected energy revenue ($/yr). A 20-year forecast of expected fuel cost ($/mmBTU). A 20-year forecast of expected fixed operations and maintenance expenses ($/yr). A 20-year forecast of expected variable operations and maintenance expenses ($/MWh) excluding fuel. Other project specific revenues such as: Renewable Energy Credits (REC) price projections REC expected revenues Production Tax Credit (PTC) price projections PTC expected revenues Power sales agreementsThis information is submitted using the Forward Capacity Tracking System (FCTS) user interface. 19XA2413.1.1.2.8Retrieve qualification determination notification.This information is retrieved using the Forward Capacity Tracking System (FCTS) user interface. 20X13.1.1.2.9Market Participants requesting Renewable Technology Resource treatment, submit election form no later than five Business Days after qualification determination notification is issued.Certification of Renewable Technology Resource form available at  HYPERLINK "http://www.iso-ne.com/markets/forward-capacity-market" http://www.iso-ne.com/markets/forward-capacity-market (search for FCM Supporting Documents under Document Type).This election is made by notifying the app. Resource TypeMaster Schedule Step/ Event IdentifierMarket Rule 1 III Section Number (13.1.2)Participant ActionDescription of Participant Deliverables / Additional Informationapp System and/or Process#D RG CI CI P1XA1413.1.2.2.4(a) Submit evidence regarding the cause of the derating if electing to have the summer Qualified Capacity set equal to the most recent summer Seasonal Claimed Capability. (b) (Reserved) (c) Submit a critical path schedule describing the measures that will be taken that will provide an amount of capacity consistent with the summer Qualified Capacity by the start of the relevant Capacity Commitment Period.This information is submitted using the Forward Capacity Tracking System (FCTS) user interface. 2XXXA15, A2713.1.2.2.5.2Submit an offer composed of separate resources or have a resources FCA Qualified Capacity administratively set by the app if the summer Qualified Capacity is greater than the winter Qualified Capacity. Market Participants can use the Seasonal Resources Capacity eBulletin Board on the apps website at HYPERLINK "http://www.iso-ne.com/markets/othrmkts_data/fcm/esra/default/main.action"http://www.iso-ne.com/markets/othrmkts_data/fcm/esra/default/main.action. The online bulletin board facilitates project sponsors with capacity resources having single-season capability to find a partner to participate in an FCA through a composite offer.An offer composed of separate resources, is submitted using the Forward Capacity Tracking System (FCTS) user interface.3XXXA1013.1.2.3Notify the app that the app-determined summer or winter Qualified Capacity does not accurately reflect the resources capability. This information is submitted using the Forward Capacity Tracking System (FCTS) user interface.4XXXA1513.1.2.3.1.1Submit a Static De-List Bid at a price greater than the Dynamic De-List Bid Threshold. A completed de-list workbook available on the apps website,  HYPERLINK "http://www.iso-ne.com/markets-operations/markets/forward-capacity-market" http://www.iso-ne.com/markets-operations/markets/forward-capacity-market (search for FCM Qualification under Document Type), and an affidavit executed by a corporate officer attesting to the accuracy of the de-list package. Market Participants must indicate whether a resource will be participating in the energy and ancillary services markets.De-list bids are submitted using the Forward Capacity Tracking System (FCTS) user interface. 5XXXA1513.1.2.3.1.2Submit a Permanent De-List Bid.For a Permanent De-List Bid at a price greater than the Dynamic De-List Bid Threshold, a completed de-list workbook available on the apps website,  HYPERLINK "http://www.iso-ne.com/markets-operations/markets/forward-capacity-market" http://www.iso-ne.com/markets-operations/markets/forward-capacity-market (search for FCM Qualification under Document Type), and an affidavit executed by a corporate officer attesting to the accuracy of the de-list package. Market Participants must indicate whether a resource will be participating in the energy and ancillary services markets.De-list bids are submitted using the Forward Capacity Tracking System (FCTS) user interface. 6XA1513.1.2.3.1.3Submit an Export Bid. De-list bids are submitted using the Forward Capacity Tracking System (FCTS) user interface.7XA1513.1.2.3.1.4Submit an Administrative Export De-List Bid. De-list bids are submitted using the Forward Capacity Tracking System (FCTS) user interface.8XA1513.1.2.3.1.4Submit documentation demonstrating a contractual obligation to sell capacity outside of the New England Control Area.Documentation must demonstrate contractual obligation to sell capacity outside of the New England Control Area. This information is submitted as an attachment (not a form) using the Forward Capacity Tracking System (FCTS) user interface.9XXXXA2613.1.2.3.1.5Submit a Non-Price Retirement Request. A sample Non-Price Retirement Request form is available in Appendix B of Planning Procedure No. 10.A Non-Price Retirement Request is submitted using the Forward Capacity Tracking System (FCTS). A Non-Price Retirement Request will be reviewed in accordance with Planning Procedure No. 10, Section 7 and Participants Agreement Section 8.2.3, where the Reliability Committee will have input and an advisory vote as part of the review of the Non-Price Retirement Request. In instances where a Non-Price Retirement Request is denied, MR 1, Section 13.2.5.2.5.2(a) shall apply, 10XXXXA1513.1.2.3.2.1.2 13.1.3.3A 13.1.3.3BSubmit net going forward cost documentation if historical data used to calculate the net going forward costs do not reflect costs that may be incurred.Adjustments to components of the bid to reflect a typical power year operations include but are not limited to: Revenues Fuel Emissions Any adjustments must include a description of the category being adjusted and the adjustment methodology.This information is submitted using the De-List Cost Workbook & Guide for Gen, Exports & Common Cost Workbook available on the apps website,  HYPERLINK "http://www.iso-ne.com/markets-operations/markets/forward-capacity-market" http://www.iso-ne.com/markets-operations/markets/forward-capacity-market (search for FCM Qualification under Document Type).11XXXXA1513.1.2.3.2.1.2 13.1.3.3A 13.1.3.3BRequest data with respect to the IMR, PER and inflation index components of the net going forward costs calculation. Submit e-mail request to  HYPERLINK "mailto:intmmufcm@iso-ne.com" intmmufcm@iso-ne.com. 12XXXXA1513.1.2.3.2.1.3 13.1.3.3A 13.1.3.3BSubmit documentation detailing expected Capacity Performance Payments. Data on the expected number and duration of Capacity Scarcity Conditions, expected average Capacity Balancing Ratio during those Capacity Scarcity Conditions, and units expected average performance during those Capacity Scarcity Conditions should be included in the documentation.This information, including any supplemental documentation, is submitted using the De-List Cost Workbook & Guide for Gen, Exports & Common Cost Workbook available on the apps website,  HYPERLINK "http://www.iso-ne.com/markets-operations/markets/forward-capacity-market" http://www.iso-ne.com/markets-operations/markets/forward-capacity-market (search for FCM Qualification under Document Type). 13XXXXA1513.1.2.3.2.1.4 13.1.3.3A 13.1.3.3BSubmit documentation detailing risk premium calculation.Details of the analysis and calculation of the risk premium and optional affidavit executed by a corporate officer attesting to the accuracy of the risk premium components. This information, including any supplemental documentation, is submitted using the De-List Cost Workbook & Guide for Gen, Exports & Common Cost Workbook available on the apps website,  HYPERLINK "http://www.iso-ne.com/markets-operations/markets/forward-capacity-market" http://www.iso-ne.com/markets-operations/markets/forward-capacity-market (search for FCM Qualification under Document Type).14XXXXA1513.1.2.3.2.1.5 13.1.3.3A 13.1.3.3BSubmit evidence supporting an opportunity cost based de-list bid. Business owner to provide additional detail and supporting evidence including but not limited to: Regulatory orders Environmental operating permits ContractsThis information is submitted using the Forward Capacity Tracking System (FCTS) user interface. 15XXXXA24.113.1.2.3.2.1.1.2 13.1.3.3A 13.1.3.3BWhere applicable, withdraw or revise Static De-List Bid.De-list bids are submitted using the Forward Capacity Tracking System (FCTS) user interface.16XXA1513.1.2.5Indicate what New Generating Capacity Resource is associated with the Existing Capacity Qualification Package. Resource TypeMaster Schedule Step/ Event IdentifierMarket Rule 1 III Section Number (13.1.3)Participant ActionDescription of Participant Deliverables / Additional Informationapp System and/or Process#D RG CI CI P1(Reserved)2(Reserved)3XA1913.1.3.5.1Submit documentation of a contract to provide capacity in the New England Control Area from outside of the New England Control Area; proof of ownership or direct control over one or more External Resources; and information about the External Resource including documentation to establish the summer and winter ratings of the resource. For system-backed import capacity, submit documentation that the import capacity will be supported by the Control Area. This information is submitted using the Forward Capacity Tracking System (FCTS) user interface. 4XA1913.1.3.5.2Submit a description of how the Capacity Supply Obligation will be met.Project Sponsors seeking to qualify New Import Capacity Resources shall submit responses to the FCA questions located in Attachment M to this Manual. The app may seek additional information under the Section III.13.1.1.2.7 consultation provisions.This information is submitted using the Forward Capacity Tracking System (FCTS) user interface. 5XA1913.1.3.5.3Submit system load and capacity projections for the external Control Area. This information is submitted using the Forward Capacity Tracking System (FCTS) user interface. 6XA1913.1.3.5.3.1Submit materials describing intervening Control Areas. Provide documentation that the neighboring and any intervening Control Area will afford the export the same curtailment priority as native load. This information is submitted using the Forward Capacity Tracking System (FCTS) user interface.  Resource TypeMaster Schedule Step/ Event IdentifierMarket Rule 1 III Section Number (13.1.4)Participant ActionDescription of Participant Deliverables / Additional InformationSystem and/or Process#D RG CI CI P1X13.1.4.1.1Register Demand Resources with the app.Refer to the app Manual for Registration and Performance Auditing for instructions on Resource and Asset registration.DR registration is performed in CAMS.2XA1813.1.4.1.2.1Submit a Measurement and Verification Plan to establish a New Demand Resources summer Qualified Capacity and winter Qualified Capacity.Forms available at:  HYPERLINK "http://www.iso-ne.com/markets-operations/markets/forward-capacity-market" http://www.iso-ne.com/markets-operations/markets/forward-capacity-market (search for FCM Qualification under Document Type). Measurement and Verification Plans are submitted through FCTS.3XA13.1.4.1.3Submit Static, Dynamic or Permanent De-List Bids for Real-Time Emergency Generation Resources.De-list bids are submitted through FCTS.4XA2,A313.1.4.2 13.1.4.2(a)Submit a New Demand Resource Show of Interest Form by a Project Sponsor seeking to offer a resource in the Forward Capacity Auction as a New Demand Resource.Project description form available at:  HYPERLINK "http://www.iso-ne.com/markets-operations/markets/forward-capacity-market" http://www.iso-ne.com/markets-operations/markets/forward-capacity-market (search for FCM Qualification under Document Type).Submission of Demand Resource Show of Interest (including the project description form) is performed in FCTS.5XA2,A313.1.4.2 13.1.4.2(a)Request by a Project Sponsor of a New Demand Resource for the app to waive submission of any information not required for evaluation of a project that is otherwise to be included in the New Demand Resource Show of Interest Form. Contact app Customer Support for additional information. 6XA1513.1.4.2.1Submit an Existing Capacity Qualification Package. The Existing Capacity Qualification Package is submitted using the Forward Capacity Tracking System (FCTS) user interface.7XA1813.1.4.2.2Submit a New Demand Resource Qualification Package.The New Capacity Qualification Package is submitted using the Forward Capacity Tracking System (FCTS) user interface.8XXXXA1813.1.4.2.2.2Submit app credit application.Credit application available at:  HYPERLINK "/participate/applications-status-changes/new-registration/credit-application" /participate/applications-status-changes/new-registration/credit-application. The new member credit application is submitted using the form on the app website.9XA1813.1.4.2.2.3Submit Measurement and Verification Plan. Forms available at:  HYPERLINK "http://www.iso-ne.com/markets-operations/markets/forward-capacity-market" http://www.iso-ne.com/markets-operations/markets/forward-capacity-market (search for FCM Qualification under Document Type).The New Capacity Qualification Package is submitted using the Forward Capacity Tracking System (FCTS) user interface.10XA1813.1.4.2.2.4Submit customer acquisition plan.The customer acquisition plan may includes but is not limited to the following information: a description of proposed customer market; the estimated size of target market and supporting documentation; a marketing plan with supporting documentation describing the manner in which customers will be recruited; and evidence supporting the viability of the marketing plan.The New Capacity Qualification Package is submitted using the Forward Capacity Tracking System (FCTS) user interface. 11XA3313.1.4.2.2.4.1 13.1.4.2.2.4.2Submit to the app, upon request, records on each customer associated with a Demand Resource with greater than 10 kW of load reduction.Market Participant must maintain records on each customer greater than 10 kW. Information must be submitted to the app upon request.12XA3413.1.4.2.2.4.3Submit a pipeline analysis by the Demand Resource Project Sponsor. Submission of Demand Resource pipeline analysis is performed in FCTS.13XA1813.1.4.2.2.5Elect multiple year Capacity Commitment Period treatment.This election is performed in FCTS.14XA1813.1.4.2.2.6Elect whether an offer may be rationed, with or without an additional specification of a single MW quantity to which offers may be rationed. This election is performed in FCTS.15XA1813.1.4.2.4 A.21Submit as a part of the New Demand Resource Qualification Package supporting documentation related to potential offers below the relevant Offer Review Trigger Price.This information is submitted using the Forward Capacity Tracking System (FCTS) user interface.16XA2413.1.4.2.5Retrieve qualification determination notification for Existing Demand Resource.This information is retrieved using the Forward Capacity Tracking System (FCTS) user interface and MIS.17XA613.1.4.2.5.2Notify the app that an app-determined summer Qualified Capacity or winter Qualified Capacity for an Existing Demand Resource does not accurately reflect the determination.Market Participant retrieves notification of Qualification for Demand Resources and submits challenge.Submission of Demand Resource challenges to summer or winter Demand Reduction Value or Qualified Capacity are submitted through FCTS.18XA1013.1.4.2.5.2Notify the app of an inaccuracy in the summer or winter Demand Reduction Value or Qualified Capacity for an Existing Demand Resource.Market Participant retrieves notification of Qualification for Demand Resources and submits challenge.Submission of Demand Resource challenges to summer or winter Demand Reduction Value or Qualified Capacity are submitted through FCTS.19XA1013.1.4.2.5.2Request a change in Demand Resource type by submitting an Updated Measurement and Verification Plan to reflect that change. Submission of Demand Resource type submitted through FCTS.20XA2413.1.4.2.5.3Retrieve Qualification Determination Notification for New Demand Resource.This information is retrieved using the Forward Capacity Tracking System (FCTS) user interface.21XA1813.1.4.3Submit documentation of Demand Reduction Value of a Demand Resource project.This information is submitted using the Forward Capacity Tracking System (FCTS) user interface.22XA1813.1.4.3.1 Submit Measurement and Verification Summary and Reference Reports. Submission of the Measurement and Verification documents is performed in FCTS.23XA1813.1.4.3.1.1Submit optional Measurement and Verification Reference Reports.Submission of Optional Measurement and Verification reference reports are performed through FCTS.24XA1213.1.4.3.1.2Submit Updated Measurement and Verification Plan.Forms available at:  HYPERLINK "http://www.iso-ne.com/markets-operations/markets/forward-capacity-market" http://www.iso-ne.com/markets-operations/markets/forward-capacity-market (search for FCM Qualification under Document Type).Submission of DR updated Measurement and Verification Plan is performed in FCTS.25XA3613.1.4.3.1.2.1Submit annual certification that the Demand Resource continues to perform in accordance with the submitted Measurement and Verification Documents.Annual Certification of Accuracy is submitted by email to  HYPERLINK "mailto:DRAudits@iso-ne.com" DRAudits@iso-ne.com.26X13.1.4.3.1.2.1Submit to the app, upon request, data regarding customers associated with a Demand Resource. Data must be in a readable electronic format as defined by the app. 27XA6 (for Existing Demand Resources), A18 (for New Demand Resources)13.1.4.3.1.3Designate in the Measurement and Verification Plan the specific methodology used to establish Demand Reduction Values. Real-Time Demand Response Resources and RTEGs must comply with the requirements of Section III.8 and Appendix III.E of Market Rule 1. Submission by Distributed Generation other than Real-Time Emergency Generation Resources of individual metering or a metering protocol consistent with the measurement and verification requirements in Market Rule 1 and the app Manuals to monitor and verify the projects Demand Reduction Values.For Existing Capacity Resources, submitted as part of updated Measurement and Verification Plan by Existing Capacity Qualification deadline. For new capacity resources, submitted as part of the Measurement and Verification Plan by the Qualification Package submission deadline.Submission of Demand Response Measurement and Verification Plan is performed in FCTS.28X13.1.4.3.1.3.1Conduct audit to establish initial Demand Reduction Value for a new Demand Resource.Refer to the app Manual for Registration and Performance Auditing for additional information on audit and testing procedures.29X13.1.4.5.1Report the load reduction and consumption or generator output of the individual assets making up a Real-Time Demand Response Asset.See OP 18 Appendix G Demand Response RTU Specification for more information. See app Manual M-28 for a data requirement matrix for Demand Resources. The matrix identifies the data required for performance settlement and auditing by Demand Resource type and metering configuration pairs. Metering configurations are described in more detail in the app Manual for Measurement and Verification of Demand Reduction Value from Demand Resources.Real-Time data is submitted through the app CFE Connected RTU. To establish an assets initial Demand Response Baseline under Section III.8 and correct data for settlement, data is submitted through the Demand Resource Market User Interface (DR MUI).30X13.1.4.5.2Reporting the generator output of a Real-Time Emergency Generation Asset. OP 18 Appendix G Demand Response RTU Specification. See app M-28 for a data requirement matrix for Demand Resources. The matrix identifies the data required for performance settlement and auditing by Demand Resource type and metering configuration pairs. Metering configurations are described in more detail in the app Manual for Measurement and Verification of Demand Reduction Value from Demand Resources.Real-Time data is submitted through the app CFE Connected RTU. To establish an assets initial Demand Response Baseline and correct data for settlement, data is submitted through the Demand Resource Market User Interface (DR MUI). 31X13.1.4.6Redefine an Active Demand Resource from a Load Zone to one or more Dispatch Zone(s). Contact app Customer Support for additional information.32XA713.1.4.6.1Retrieve Dispatch Zone information.Contact app Customer Support for additional information.33X13.1.4.6.2.1Disaggregate a Real-Time Demand Response Resource into one or more Real-Time Demand Response Resources located within one or more Dispatch Zones within the original Load Zone. Contact app Customer Support for additional information.34X13.1.4.6.2.2Disaggregate a Real-Time Emergency Generation Resource into one or more Real-Time Emergency Generation Resources located within one or more Dispatch Zones within the original Load Zone. Contact app Customer Support for additional information. Resource TypeMaster Schedule Step/ Event IdentifierMarket Rule 1 III Section Number (13.1.5 - 9)Participant Action/Description of Participant Deliverables / Additional InformationSystem and/or Process#D RG CI CI P1XXXXA2713.1.5 Submit composite offer. Forming and submitting a composite offer is completed in three steps: Summer Resource creates composite offer. Composite offer is Pending. Winter resource Lead Market Participant designates resources to composite offer created by summer resource. This step acts as the winter resource confirmation. Composite offer is Pending. Summer resource submits composite offer to app. Composite offer is Confirmed. When entering into composite offers, Demand Resources must enter in the Qualified Capacity amounts (amount grossed up for losses), NOT the Demand Reduction Value. New Capacity Resources with summer greater than winter that chooses to have a multi-year Capacity Supply Obligation cannot participate in a composite offer.Composite offers are submitted using the FCTS.2XXXXA2713.1.5 Modify composite offer.Composite offers can be modified in FCTS until the composite offer deadline.Composite offers can be modified using the FCTS.3XXXXA2713.1.5 Withdraw composite offer.Before the composite offer deadline a composite offer can be withdrawn from FCTS and will not be submitted into the Forward Capacity Auction.Composite offers can be withdrawn using the FCTS.4XXXX13.1.5 Composite offer validation based on Locational Rules (automatically performed by FCTS).Composite Offer Validations Locational Rules Summer resources in import constrained Capacity Zones may only pair with winter resources located in the same Capacity Zone Summer resources in export constrained Capacity Zones may pair with any winter resource that is NOT located in a different export constrained Zone Summer resources in the Rest of Pool may pair with any resource that is NOT located in an export constrained ZoneAutomatic in FCTS.5X13.1.5Composite offer validation (automatically performed by FCTS) for Demand Resources.Composite Offer Validations Demand Resources Demand Resources may participate in composite offers Real-Time Emergency Generators (RTEG) may only participate as a winter resource in a composite offer if the summer resource is also a RTEG When entering into composite offers, Demand Resources must enter in the Qualified Capacity amounts (amount grossed up for losses), NOT the Demand Reduction ValueAutomatic in FCTS.6XComposite offer validation for Import Capacity Resources.Composite Offer Validations Import Resources Import Capacity Resources may participate in composite offers When evaluating locational constraints of an Import Capacity Resource, the capacity is treated as though it is in the Capacity Zone to which it is mapped Automatic in FCTS.7XXXXComposite offer validation for New Capacity Resources.Composite Offer Validations New Capacity Resource Summer and winter MW limits for New Capacity Resources are based off the Resources Qualified Capacity values Where the summer resource is a New Capacity Resource project that has a mutually exclusive Existing Resource, two composite offers may be submitted: One for the New Capacity Resource project and one for the Existing Capacity Resource Where the summer resource is a New Capacity Resource project that is an increase, treated as new capacity, to an Existing Capacity Resource, two composite offers may be submitted: One for the incremental New Capacity Resource and one for the Existing Capacity ResourceAutomatic in FCTS.8XXXA2813.1.5.AReceive notification from app of FCA Qualified Capacity.Notification of the quantity (MW) of FCA Qualified Capacity for new and existing resources is provided via the FCTS.9XXA3113.1.6Submit self-supply designation. Designating capacity from a resource as Self-Supply allows a Load Serving Entity (LSE) to satisfy its Capacity Load Obligations using resources owned or under contractual obligation of the LSE. Submitting a Self-Supply designation is a two step process: Lead Market Participant of a resource selects a specific LSE and Capacity Zone and designates the amount of Qualified MW from a specific resource to be considered as self-supplied MW. LSE confirms the Self-Supply designations applicable to them. These two steps must be completed by the Self-Supply submittal deadline. Throughout the designation process, the FCTS will enforce various validation rules. Indicate if any Specifically Allocated Capacity Transfer Rights are used in the Self-Supply Designation. The total amount of capacity designated as Self-Supply for a LSE is limited to this calculated projected share of ICR per Capacity Zone. The maximum amount of capacity that a resource may designate as Self-Supply is the lower of their summer and winter Qualified Capacity values. A resource located in an Export Constrained Capacity Zone may not Self-Supply load located in another Capacity Zone. Any capacity that already received an obligation from a prior FCA by choosing a multi-year Capacity Commitment Period may not be designated as Self-Supply. New Capacity Resources with a Project Type of increase above threshold, Environmental Upgrade, or Repowering. The maximum amount of capacity that can be designated as Self-Supply is the minimum of the New Capacity Resource Qualified MW and the Existing Capacity Resource Qualified MW. New Capacity Resources with a Project Type Incremental Capacity, the Existing Capacity resource must be designated as Self-Supply up to its maximum before any allocation of self-supplied MW can be made to the New Capacity Project.Designated in the FCTS.9aXX13.1.6Confirmation of self-supply designation by LSE.A LSE may not confirm more self-supplied capacity than their projected share of Installed Capacity Requirement.Confirmation is made in the FCTS.10XXXX13.1.7Consult with Internal Market Monitor.Internal Market Monitor may consult with the Project Sponsor or Market Participant, as appropriate, to seek clarification, or to address questions or concerns regarding the materials submitted.The Internal Market Monitor will contact the Project Sponsors or Market Participant directly.11XXXX13.1.8 13.1.8(a)-(c), (e) 13.1.8(d)Download published offer and bid information. See Market Rule 1 for details on the offer and bid information published by the app.Offer and bid information can be downloaded in reports published on the apps website at HYPERLINK "http://www.iso-ne.com"www.iso-ne.com.12XXXX13.1.9See Financial Assurance Policy (Exhibit IA to Section I of the Tariff) Note: Market Rule 1 does not reflect all instances of Financial Assurance Policy requirements.Contact Market & Credit Risk Dept. 13XX5 Business Days after A2813.1.9.1Satisfaction by a New Capacity Resource (including for the fourth and future auctions, Conditional Qualified new resources) of the financial assurance requirements described in the Financial Assurance Policies. Payment by the Project Sponsor for a Non-Commercial Capacity Resource of the financial assurance deposits specified in the Financial Assurance Policy.See Financial Assurance Policy Note: Market Rule 1 does not reflect all instances of Financial Assurance Policy requirements.Contact Market & Credit Risk Dept. 14XXAs described in the Financial Assurance Policy Section VII.B.2.b13.1.9.2Satisfaction by a New Capacity Resource (including for the fourth and future auctions, Conditional Qualified new resources) of the financial assurance requirements described in the Financial Assurance Policy.See Financial Assurance Policy Note: Market Rule 1 does not reflect all instances of Financial Assurance Policy requirements.Contact Market & Credit Risk Dept. 15XXXX13.1.9.2.3See Financial Assurance Policy Note: Market Rule 1 does not reflect all instances of Financial Assurance Policy requirements.Contact Market & Credit Risk Dept. 16X13.1.9.2.4See Financial Assurance Policy Note: Market Rule 1 does not reflect all instances of Financial Assurance Policy Requirements.Contact Market & Credit Risk Dept. 17XXXX13.1.9.3Submission of Qualification Process Cost Reimbursement Deposit by a Project Sponsor for each New Capacity Show of Interest Form or New Demand Resource Show of Interest Form submitted for purposes of qualifying for a Forward Capacity Auction or a reconfiguration auction.Please note that the payment terms follow the Billing Policy. (Exhibit ID to Section I of the Tariff)Contact app Finance. 18XXXXAs invoiced13.1.9.3Withdrawal of a project by failing to pay the Qualification Process Cost Reimbursement Deposit when due.Please note that the payment terms follow the Billing Policy.Contact app Finance. 19XXXXAs invoiced13.1.9.3Payment of annual app invoice for costs of the app, its consultants and reasonably-incurred costs of the affected Transmission Owner(s), associated with the qualification process and critical path schedule monitoring for each resource subject to payment of the Qualification Process Cost Reimbursement Deposit. Withdrawal of a project by failing to pay an annual app invoice for costs of the app, its consultants and reasonably-incurred costs of the affected Transmission Owner(s), associated with the qualification process and critical path schedule monitoring for each resource subject to payment of the Qualification Process Cost Reimbursement Deposit.Please note that the payment terms follow the Billing Policy.Contact app Finance. 20XXAs invoiced13.1.9.3.1Request a waiver of a portion of the Qualification Process Cost Reimbursement Deposit for a project that has an active Interconnection Request and an executed Feasibility Study Agreement or System Impact Study Agreement.Contact app Resource Analysis and Integration Department.21XXXA1513.1.11For Capacity Commitment Periods beginning with June 1, 2018 through May 31, 2021, elect to opt-out of any remaining years associated with multiple year Capacity Commitment Period treatment. This election is made by submitting written notification to the app.  2.2 Forward Capacity Auction #Resource TypeMaster Schedule Step/ Event IdentifierMarket Rule 1 III Section NumberParticipant ActionDescription of Participant Deliverables/Additional Information app System and/or ProcessD RG CI CI P1XXXXA3513.2.3.2(a)Submit a New Capacity Offer (New Generating Capacity Resource, New Import Capacity Resource, or New Demand Resource).Capacity offers are submitted using the Auction System user interface. 2XXXXA3513.2.3.2(d)Submit a Dynamic De-List Bid. For the portion of a resource designated as Self-Supply, Existing Resources cannot enter Dynamic De-List Bids within the Forward Capacity Auction (FCA).Dynamic De-List Bids are submitted using the Auction System user interface. 3XXXXA3513.2.3.2(g)Request an opportunity to complete or correct an offer or bid after the end of a round.Contact app Customer Support for additional information. 4XXX~ 6 months after A38 13.2.5.2.5.1(b)(i) For Permanent De-List Bids, notify the app of the manner of payment: (i) on the basis of its Permanent De-List bid, or (ii) under the terms of a cost-of-service agreement. If a Market Participant elects a cost of service agreement, the agreement must be filed with and approved by the Commission. If a cost of service agreement is not approved by the Commission, payment will be made based upon the Resource Permanent De-List Bid. The Market Participant must provide the app with completed copy of cost-of-service agreement pursuant to Section III, Appendix I and supporting data for Schedules in format posted on app website. The Market Participant is responsible for making the appropriate Commission filing. The app will calculate payments based on the FCA clearing price each month and allocate those payments to Capacity Load Obligation. In addition, a payment will be calculated based on the amount of the bid or cost of service agreement which exceeds the FCA clearing price. These payments shall be allocated to Regional Network Load in the applicable Reliability Region. Regional Network Load values will be submitted no later than the 20th day of the month following the settlement month. Send notice of election to the Vice President of Market Operations within six months after the app files the results of the FCA with the Commission. 5XXX~ 6 months after A3813.2.5.2.5.1(c)(i) and 13.2.5.2.5.1(d)For rejected Non-Price Retirement Requests that have not elected to retire, notify the app of the manner of payment: (i) in the same manner as resources with Capacity Supply Obligations, or (ii) under the terms of a cost-of-service agreement. If a Market Participant elects a cost of service agreement, the agreement must be filed with and approved by the Commission. If a cost of service agreement is not approved by the Commission, payment will be made in the same manner as other listed capacity resources. The Market Participant must provide the app with completed copy of cost-of-service agreement pursuant to Section III, Appendix I and supporting data for Schedules in the format posted on app website. Participant is responsible for making the appropriate Commission filing. The app will calculate payments based on the FCA clearing price each month and allocate those payments to Capacity Load Obligation. In addition, a payment will be calculated based on the amount of the cost of service agreement which exceeds the FCA clearing price. These payments shall be allocated to Regional Network Load in the applicable Reliability Region. Regional Network Load values will be submitted no later than the 20th day of the month following the settlement month.Regional Network Load values will be submitted to the app by the Assigned Meter Reader via the Regional Network Load user interface. Send notice of election to app VP of Market Operations within 6 months after the app files the results of the FCA with the Commission. 6XX13.2.5.2.5.2If applicable, for rejected Non-Price Retirement requests, notify appropriate State Utility Commissions, the app, and NEPOOL Committees of the intent to make an application to the Federal Energy Regulatory Commission to receive just and reasonable compensation for the capital investment.Make the appropriate filing with the Commission. Send app notice to Vice President of Market Operations and Legal of intent to make a 205 Filing. XX13.2.5.2.5.3(a)(ii) 13.2.5.2.5.3(b)(ii)Notify the app that a Resource is retiring earlier than the Capacity Commitment Period for which its non-partial Permanent De-List Bid or Non-Price Retirement Request was approved.Participant to send notification via a memo emailed to HYPERLINK "mailto:ProposedPlan@iso-ne.com"ProposedPlan@iso-ne.com stating the Participants intentions.7XXXXNo later than 15 days before A3513.2.5.2.5.3(a)(iii) 13.2.5.2.5.3(b)(i) 13.2.5.2.5.3(c)Notify the app that the resource will retire coincident with the commencement of the Capacity Commitment Period.  2.3 Critical Path Monitoring Resource TypeMaster Schedule Step/ Event IdentifierMarket Rule 1 III Section NumberParticipant ActionDescription of Participant Deliverables/Additional Informationapp System and/or ProcessD RG CI CI P1XXX13.3.1.2Request that the app continue to monitor a resources compliance with its critical path schedule. Applicable to a New Capacity Resource where no capacity from a new resource that was required to submit a critical path schedule in the qualification process clears in the Forward Capacity Auction, or if such a resource does not submit an offer in the Forward Capacity Auction.Election is made using the Forward Capacity Tracking System (FCTS).2XXX13.3.2Submit a critical path schedule report to the app for each new resource being monitored. This information is submitted using the Forward Capacity Tracking System (FCTS) user interface. 3XXX13.3.2.1Submit updated critical path schedule. This information is submitted using the Forward Capacity Tracking System (FCTS) user interface.4XXX13.3.2.2(a) Submit a critical path schedule updated report demonstrating each critical path schedule milestone that has been achieved since the last report was submitted.Include documentation of substantial site construction that demonstrates that the amount of money expended on construction activities occurring on the project site has exceeded 20 percent of the construction financing costs. This provision is not applicable to Demand Resource projects installed at multiple facilities and Demand Resource projects from a single facility with a Demand Reduction Value of less than 5 MW (discussed in Section III.13.3.2.2(b)).This information is submitted using the Forward Capacity Tracking System (FCTS) user interface. 5X13.3.2.2(b)Submit a critical path schedule updated report for a Demand Resource demonstrating that each critical path schedule milestone that has been achieved since the last report was submitted. This provision is not applicable to Demand Resource projects installed at multiple facilities and Demand Resource projects from a single facility with a Demand Reduction Value of less than 5 MW (discussed in Section III.13.3.2.2(b)). The submittal should include documentation of substantial project completion showing the total offered Demand Reduction Value achieved as of target dates.This information is submitted using the Forward Capacity Tracking System (FCTS) user interface. 6XXX13.3.3Submit written report detailing progress toward meeting revised critical path schedule.The information should be similar to that submitted in the quarterly reports, but on a monthly basis.This information is submitted using the Forward Capacity Tracking System (FCTS) user interface.7XXX13.3.6Withdrawal of a resource from critical path schedule monitoring. Submit memo via the FCTS indicating when and why the resource has decided to terminate critical path schedule monitoring. Upon termination of critical path schedule monitoring, the terminated resource will not be eligible to participate as a qualified resource in future FCAs. A new Show of Interest will need to be submitted should the resourced decide at a later time to participate in qualification for participation in a future FCA.This information is submitted using the Forward Capacity Tracking System (FCTS) user interface.  2.4 Reconfiguration Auction Resource TypeMaster Schedule Step/ Event IdentifierMarket Rule 1 III Section NumberParticipant ActionDescription of Participant Deliverables/Additional Informationapp System and/or ProcessD RG CI CI P1XXXX13.4.2.1Submit a supply offer in a reconfiguration auction. For a supply offer, It should specify a resource; It is allowed up to five segments of MW and price values; The amount of MW entered must be greater than zero; The price value must be greater than or equal to zero.Submitted using the Forward Capacity Market Reconfiguration Auction user interface. 2XXXX13.4.2.1.3(a) 13.4.2.1.3(b)Submit a written plan to the app, with any necessary supporting documentation, describing the measures that will be taken to address the reduction and/or demonstrating that the resource will be able to provide an amount of capacity consistent with its total Capacity Supply Obligation for the Capacity Commitment Period by the start of all months in that Capacity Commitment Period in which the resource has a Capacity Supply Obligation.Resources that have a significant decrease in capacity may submit a Restoration Plan to explain how the obligation will be met prior to the relevant Capacity Commitment Period during a 10 Business Day window following the initial publication of the Significant Decrease in Capacity. If the Restoration Plan is submitted and acceptable, the Resources Summer and Winter ARA Qualified Capacity values will be restored.This information is submitted using the Forward Capacity Tracking System (FCTS) user interface. 2aX13.4.2.1.3(a) 13.4.2.1.3(b)Submit written information to the app to explain seasonal performance values.In the submittal of a Restoration Plan made in response to a significant decrease in capacity for an Intermittent Power Resource in qualification for the third annual Reconfiguration Auction for a given Capacity Commitment Period the Lead Market Participant shall explain any reductions in inputs (e.g., wind speeds, solar levels) that contributed to the significant reduction. The Lead Market Participant shall also provide, if known, an explanation of why the actual input reductions differed from the long-term expected resource levels that formed part of the methodology originally used to qualify the resource for the given Capacity Commitment Period.This information is submitted using the Forward Capacity Tracking System (FCTS) user interface. 3XXXX13.4.2.1.3(c)Submit Sub-Annual Capacity Supply Obligation Bilaterals to cover the deficiency for the months of the Capacity Commitment Period in which the Capacity Supply Obligation is associated with participation in an offer composed of separate resource. If the Restoration Plan is denied and the Resource is not able to cover its significant decrease in capacity through the bilateral, the app will submit a corresponding Demand Bid for all or part of the resource at the Forward Capacity Auction Starting Price in the third annual Reconfiguration Auction. During the Annual Bilateral Window Open period, only the Lead Market Participant associated with a resource that is identified as either Monthly Non-Commercial Capacity or Monthly Significant Decrease Composite Resource Capacity is allowed to submit a Sub-Annual Bilateral. Such Bilateral consists of a series of single-month CSO Bilaterals, each monthly bilateral corresponding to an individual identified month. If an app Mandatory Demand Bid is entered for a particular Resource, the Lead Market Participant is able to view the portion of the demand bid that is the app mandatory Demand Bid, but not allowed to enter or edit that portion.Submitted using the FCM CSO Bilateral Contracts user interface. For significant decrease information on a Resource level and monthly Qualification information and FCM CSO Bilateral Contracts (for sub-annual CSO Bilateral Contract submission). Submitted using the FCM Reconfiguration Auction user interface for app mandatory Demand Bid information.4XXXX13.4.2.2 13.4.2.2(a)-(b)Submit demands bids in reconfiguration auctions.A demand bid, Should specify a resource; Is allowed up to five segments of MW and price values; The amount of MW entered must be greater than zero; The price value must be greater than or equal to zero. If a mandatory app Demand Bid is entered for the resource submitting Bids/Offers, the Lead Market Participant is not allowed to edit any portion that is an app mandatory Demand Bid, and only allowed to edit the other four Demand Bid segments of MW and price values that are not part of the app mandatory Demand Bid.Submitted in the FCM Reconfiguration Auction user interface. 2.5 Bilateral Contracts Resource TypeMaster Schedule Step/ Event IdentifierMarket Rule 1 III Section NumberParticipant ActionDescription of Participant Deliverables/Additional Informationapp System and/or ProcessD RG CI CI P1XXXX13.5.1Shed a Capacity Supply Obligation by entering into a bilateral transaction to transfer some or all of the Capacity Supply Obligation to resource having Qualified Capacity for that Capacity Commitment Period that is not already obligated. One of the two parties associated with a bilateral contract, either the Lead Market Participant for the Capacity Supply Obligation transferring resource or the Lead Market Participant for the Capacity Supply Obligation acquiring resource, must submit the following information to the app as a submitting Lead Market Participant: The amount of the Capacity Supply Obligation being transferred in MW amounts (greater than zero and no greater than the available transferring MW) The price of the transaction (greater than or equal to zero) The duration of the transaction The transferring or the acquiring resource that the submitting Lead Market Participant is transacting with The confirming Lead Market Participant ID number The Lead Market Participant confirming the contract is referred to as the confirming Lead Market Participant. Submitted using the FCM CSO Bilateral Contracts user interface (a SMD application). 2XXXX13.5.1.1.1Submit an annual Capacity Supply Obligation Bilateral, a Monthly Capacity Supply Obligation Bilateral and confirmation of a Capacity Supply Obligation Bilateral.Lead Market Participants can submit Capacity Supply Obligation Bilaterals before or during submittal windows, as defined by the app. A bilateral contract must be confirmed by the confirming Lead Market Participant specified by the submitting Lead Market Participant no later than the end of the relevant submittal window. The app will apply the Capacity Supply Obligation Bilateral limitations criteria described in Section III.13.5.1 to each Capacity Supply Obligation Bilateral during the submittal window. The confirming Lead Market Participant can only confirm bilateral contracts for the resource it is associated with. A Capacity Supply Obligation Bilateral cannot be terminated by the submitting Lead Market Participant once the submittal window is closed. If the transferring resource and acquiring resource belong to same Lead Market Participant, then the Capacity Supply Obligation Bilateral will be automatically confirmed once it is entered. The Lead Market Participant can withdraw a submitted Capacity Supply Obligation Bilateral when the submittal window is open. Either party to a Capacity Supply Obligation Bilateral that has been confirmed may withdraw the contract, and the other party has to confirm the withdrawal to make the action successful. Both actions have to be completed when the submittal window is open.Submitted using the FCM CSO Bilateral Contracts user interface (a SMD Application). 3XXXX13.5.2.1Shed a Capacity Load Obligation by entering into a bilateral transaction to transfer some or all of the Capacity Load Obligation to a Market Participant seeking to acquire a Capacity Load Obligation. A Capacity Load Obligation Bilateral must be in whole calendar month increments. The term of a Capacity Load Obligation Bilateral may not exceed one year and must begin and end within the same Capacity Commitment Period. A monthly Capacity Load Obligation Bilateral can be submitted when the window opens for Capacity Load Obligation Bilaterals. One of the two parties associated with a Capacity Load Obligation Bilateral, either the Capacity Load Obligation Transferring Participant or the Capacity Load Obligation Acquiring Participant, must submit the following information to the app as a submitting Lead Market Participant: The amount of the Capacity Load Obligation being transferred in MW amounts up to three decimal places (greater than zero) The term of the transaction The submitting Market Participant identification number The confirming Market Participant identification number The Capacity Zone in which the transaction is located Description( free form field for customer entry) (optional) The party other than the submitting Market Participant is called the confirming Market Participant.Capacity Load Obligation Bilaterals are entered via the Internal Transactions Contract user interface (a SMD Application). These validations are enforced by the settlement process.4XXXX13.5.2.1.1Submit Capacity Load Obligation Bilateral and confirmation of a Capacity Load Obligation Bilateral.A Capacity Load Obligation Bilateral must be submitted to the app no later than 12:00 pm on the second Business Day after the end of the month. A Capacity Load Obligation Bilateral submitted after 12:00 pm on the second Business Day after the Obligation Month, will not be included in the initial settlement of payments and charges for the FCM. A Capacity Load Obligation Bilateral can only be confirmed by the confirming Market Participant when the window for submitting Capacity Load Obligation Bilaterals is open for confirmation. The window for confirmation is the same as the window for submissions. The following information on a confirmed contract may be revised and submitted throughout the resettlement process by the parties to the transaction: MW amount (if original contract was submitted in monthly schedules) Term End date only on monthly boundaries (If shortened, latter months are terminated.) Any revisions must be confirmed by the other party. If Contract Only confirmation level is selected at the time of initial contract submission, the monthly MW amount revisions are confirmed automatically. The window for confirmation of revisions is the same as the window for submissions. A Capacity Load Obligation Bilateral may be terminated throughout the resettlement process by either party to the transaction. Any termination must be confirmed by the other party. The window for Capacity Load Obligation Bilateral termination is the same as the window for submissions.Capacity Load Obligation Bilaterals are entered via the Internal Transactions Contract user interface (a SMD Application). These validations are enforced in the settlement process.5XXX13.5.3Supplement a Resources availability during a Shortage Event by entering into a Supplemental Availability Bilateral. A Lead Market Participant may designate a resource as a Supplemental Capacity Resource by the deadline for submission of Supply Offers in the Day-Ahead Energy Market as described in Market Rule 1 Section III.13.5.3. A Supplemental Availability Bilateral may be entered by the Lead Market Participant for the resource after an Operating Day during which a Shortage Event occurred.Supplemental Availability Bilaterals are entered via the Internal Transactions Contract user interface (a SMD Application).6XXX13.5.3.1.2Designate a Supplemental Capacity Resource. Only the Lead Market Participant for the Resource can designate the Resource. The Lead Market Participant needs to specify the duration and MW amount during the designation. The MW amount of the designation must be greater than zero and less than difference of the Resources CNRC minus the Resources Capacity Supply Obligation for the entire duration. Any Resource flagged as an Intermittent Power Resource or Settlement Only Resource is ineligible for designation. This information is submitted using the Forward Capacity Tracking System (FCTS) user interface. 7XXX13.5.3.2 13.5.3.1Submit a Supplemental Availability Bilateral for a resource previously designated as a Supplemental Capacity Resource for a term that included a Shortage Event. Assign to a Supplemental Capacity Resource by a resource previously designated as a Supplemental Capacity Resource for a term that included a Shortage Event of some or all of its available capability up to its designated supplemental capacity in each hour of that Shortage Event. Only the Lead Market Participant for the Supplemental Capacity Resource is allowed to submit a Supplemental Availability Bilateral. The Supplemental Capacity Resource must not be supplemented through another confirmed Supplemental Availability Bilateral during the duration of the contract. The Supplemented Capacity Resource cannot supplement through another confirmed Supplemental Availability Bilateral during the duration of the contract. A Lead Market Participant may submit one or more Supplemental Availability Bilaterals utilizing a resource that has been designated as a Supplemental Capacity Resource. The confirmed contracts are evaluated as part of the settlement. Only contracts that meet the following criteria, for all hours of the contract, will be included in the settlement: The contract length cannot exceed one calendar month The contract must include at least one hour of a preliminary or finalized Shortage Event. The contract MW does not exceed the Supplemental Capacity Resources designated MW reduced by any previously accepted contracts. The contract MW does not exceed the Supplemental Capacity Resources Available MW reduced by any previously accepted contracts. Contracts that do not meet these criteria will not be considered in the settlement no partial contract values will be calculated. Contracts shall be evaluated in the order in which they were confirmed.Supplemental Availability Bilaterals are entered via the Internal Transactions Contract user interface (a SMD Application). These validations are enforced in the settlement process.8XXXSee Additional Information Column13.5.3.2.1Submit a Supplemental Availability Bilateral and confirmation of a Supplemental Availability Bilateral.A Lead Market Participant may submit a Supplemental Availability Bilateral no earlier than 12:01 a.m. on the day following the Operating Day and no later than the resettlement deadline of the Obligation Month for which the contract has been entered. To be included in the initial settlement, the contract must be submitted and confirmed no later than 12:00 pm on the second Business Day after the end of the Obligation Month or at such later deadline as specified by the app upon notice to Market Participants. A Lead Market Participant may confirm, modify or terminate a Supplemental Availability Bilateral no later than the applicable deadline for submission of the Supplemental Availability Bilateral. A new Supplemental Availability Bilateral or a previously confirmed and modified Supplemental Availability Bilateral must be confirmed by the Lead Market Participant of the Supplemented Capacity Resource. If the Lead Market Participant is the same for both the Supplemental and Supplemented Capacity Resource, the contract shall be considered confirmed upon submission. The Lead Market Participant of the Supplemental Capacity Resource or the Lead Market Participant of the Supplemented Capacity Resource may initiate the termination of a Supplemented Availability Bilateral Contract. The termination of a contract must be confirmed by the Lead Market Participant of the party that did not initiate the termination. If the Lead Market Participant is the same for both the Supplemental and Supplemented Capacity Resource, the contract shall be considered terminated upon submission. The Lead Market Participant of the Supplemental Capacity Resource may cancel an unconfirmed Supplemental Availability Bilateral.Supplemental Availability Bilaterals are entered via the Internal Transactions Contract user interface (a SMD Application). These validations are enforced in the settlement process.9XXX13.5.3.2.2Submit Supplemental Availability Bilateral. A Supplemental Availability Bilateral submission must include the following information: The duration of the Supplemental Availability Bilateral (one or more consecutive hours in the same Obligation Month) The Supplemental Capacity Resource The Supplemented Capacity Resource The MW amount being supplemented (less than or equal to the Supplemental Capacity Resources Supplemental Capacity Resource Available MW)Supplemental Availability Bilaterals are entered via the Internal Transactions Contract user interface. These validations are enforced in the settlement process.10XXX13.5.3.2.3Offer the resource into the Real-Time Energy Market such that the capacity designated is available. Offer the resource into the Real-Time Energy Market such that: The Resource is on-line during the Shortage Event, and the MW amount of capacity designated is less than or equal to the difference between the resources Economic Maximum Limit and the Supplemental Capacity Resources Capacity Supply Obligation; OR The Resource is offline, and the MW amount of capacity designated is less than or equal to the difference between the sum of the Supplemental Capacity Resources Real-Time Reserve Designations of TMNSR and TMOR, and the Supplemental Capacity Resources Capacity Supply ObligationSupplemental Availability Bilaterals are entered via the Internal Transactions Contract user interface. These validations are enforced in the settlement process. 21XXXA1513.1.11For Capacity Commitment Periods beginning with June 1, 2018 through May 31, 2021, elect to opt-out of any remaining years associated with multiple year Capacity Commitment Period treatment. This election is made by submitting written notification to the app.  2.6 Rights and Obligations Resource TypeMaster Schedule Step/Event IdentifierMarket Rule 1 III Section NumberParticipant ActionDescription of Participant Deliverables/Additional Informationapp System and/or ProcessD RG CI CI P1X13.6.1.1.1Submit energy market Offer Data.See the eMkt User Guide at  HYPERLINK "http://www.iso-ne.com/participate/support/user-guides" http://www.iso-ne.com/participate/support/user-guides.Demand Bid and Supply Offer data is submitted to the app using the eMkt system. 2X13.6.1.1.2Re-declaration to the app of any changes to the parameters of a Day-Ahead Energy Market or Real-Time Energy Market offer that occur in real time. See the eMkt User Guide at  HYPERLINK "http://www.iso-ne.com/participate/support/user-guides" http://www.iso-ne.com/participate/support/user-guides.Demand Bid and Supply Offer data is submitted to the app using the eMkt system. 3XReserved4X13.6.1.1.5(a) 1.7.11Conduct a summer Seasonal Claimed Capability Audit at least once every Capability Demonstration Year and a winter Seasonal Claimed Capability Audit at least once in the previous three Capability Demonstration Years to establish summer and winter Seasonal Claimed Capability ratings.See OP-23 Generation Resource Auditing, SOP-OUTSCH 0010.0020 Scheduling Capability, Claim 10_30 and MRR Audits, and CROP.45002 Auditing.5X13.6.1.1.5(b)Submit Operating Data for Generating Capacity Resources having a Capacity Supply Obligation.Information describing the GADS Data collection process can be found at HYPERLINK "http://www.iso-ne.com/genrtion_resrcs/gads/"http://www.iso-ne.com/genrtion_resrcs/gads/. Information is submitted using PowerGADS found at  HYPERLINK "https://iso-ne.powergads.com/" https://iso-ne.powergads.com/.7X13.6.1.2.1Submit energy market Offer Data.See the User Guide for External Transactions Using EES at  HYPERLINK "http://www.iso-ne.com/participate/support/user-guides" http://www.iso-ne.com/participate/support/user-guides. Enhanced Energy Scheduling (EES) system.8X13.6.1.2.2(a)Submit information regarding External Transactions associated with resource or Control Area backed Import Capacity Resources.  Contact app Customer Support for additional information 9X13.6.1.2.2(b)Request approval of planned and maintenance outage schedules for Import Capacity Resources. Resource backing Import Capacity Resources must request approval of planned and maintenance outage schedules following the requirements detailed in app OP5 for a Generator. Control Area backed Import Capacity Resources are prohibited from requesting planned and maintenance outages. Procedures for scheduling outages are described in OP-5 Generator and Dispatchable Asset Related Demand Maintenance and Outage Scheduling.Planned outage requests submitted via e-mail to: opamoreq@iso-ne.com. Maintenance outage requests are submitted to the Generation Coordinator at 413-535-4378. 10X13.6.1.2.2(c)Comply with outage schedule changes issued by the app.Procedures for scheduling outages are described in OP-5 Generator and Dispatchable Asset Related Demand Maintenance and Outage Scheduling.Planned outage requests submitted via e-mail to: opamoreq@iso-ne.com. Maintenance outage requests are submitted to the Generation Coordinator at 413-535-4378.10AX13.6.1.2.2(d)Provide for each External Transaction a reference to the associated Import Capacity Resource.Contact app Customer Support for additional information.10BX13.6.1.2.3(c)Notify the app of outage schedules.Resource backing Import Capacity Resources at an external interface for which the enhanced scheduling provisions in Section III.1.10.7.A are implemented must notify the app of outage schedules in accordance with app OP-5 Generator and Dispatchable Asset Related Demand Maintenance and Outage Scheduling.Planned outage notifications submitted via e-mail to: opamoreq@iso-ne.com. Maintenance outage notifications are submitted to the Generation Coordinator at 413-535-4378. 10CX13.6.1.2.3(d)Provide for each Coordinated External Transaction submitted to the Day-Ahead Energy Market a reference to the associated Import Capacity Resource.Contact app Customer Support for additional information.11X13.6.1.3.1Submit Intermittent Power Resource output projections. Contact app Customer Support for additional information.12X13.6.1.3.1Submit offers in the Real-Time Energy Market. See the eMkt User Guide at  HYPERLINK "http://www.iso-ne.com/participate/support/user-guides" http://www.iso-ne.com/participate/support/user-guides.Bid and Offer data is submitted to the app using the eMkt system. 13X13.6.1.3.3(a)Submit operational data to allow determination of summer and winter Seasonal Claimed Capability ratings.Contact app Customer Support for additional information. 14X13.6.1.3.3(b) 13.6.1.4.2(b)Submit Operating Data. Information describing the GADS Data collection process and requirements can be found at HYPERLINK "http://www.iso-ne.com/genrtion_resrcs/gads/"http://www.iso-ne.com/genrtion_resrcs/gads/. app does not require all Intermittent Power and Settlement Only Resources to submit GADS Data.Information is submitted using PowerGADS found at  HYPERLINK "https://iso-ne.powergads.com/" https://iso-ne.powergads.com/.15X13.6.1.3.3(c) Request approval of planned and maintenance outage schedule.Intermittent Power Resources must request approval of planned and maintenance outage schedules, following the requirements detailed in app OP-5 for a generator. Procedures for scheduling outages are described in OP-5 Generator and Dispatchable Asset Related Demand Maintenance and Outage Scheduling.Planned outage requests submitted via e-mail to: opamoreq@iso-ne.com. Maintenance outage requests are submitted to the Generation Coordinator at 413-535-4378. 16X13.6.1.4.2(a)Submit operational data to allow determination of summer and winter Seasonal Claimed Capability ratings.Contact app Customer Support for additional information. 17X13.6.1.5.2Submit updated two-day forecasts of a Demand Resources Forecast Hourly Demand Reduction.Forecast must be submitted for each Operating Day by a Market Participant with a Real-Time Demand Response Resource or a Real-Time Emergency Generation Resource.Contact app Customer Support for additional information. 18X13.6.1.5.3Submit a monthly forecast of the resources monthly maximum Forecast Hourly Demand Reduction for each of the next 12 months. Data must be submitted by a Market Participant with a Real-Time Demand Response Resource or a Real-Time Emergency Generation Resource. Contact app Customer Support for additional information. 18aX13.6.1.5.4Request a Seasonal DR Audit or Commercial Operation Audit through the DR Audit and Testing Tool at  HYPERLINK "https://smd.iso-ne.com" https://smd.iso-ne.comContact app Customer Support for additional information.19X13.6.2.1.1.1Submit an offer into the Day-Ahead Energy Market of a Generating Capacity Resource having no Capacity Supply Obligation.See the eMkt User Guide at  HYPERLINK "http://www.iso-ne.com/participate/support/user-guides" http://www.iso-ne.com/participate/support/user-guides.Demand Bid and Supply Offer data is submitted to the app using the eMkt system. 20X13.6.2.1.1.2Self schedule in the Real-Time Energy Market. See the eMkt User Guide at  HYPERLINK "http://www.iso-ne.com/participate/support/user-guides" http://www.iso-ne.com/participate/support/user-guides.Bid and Offer data is submitted to the app using the eMkt system. 21X13.6.2.1.2(a) 1.7.11Conduct a summer Seasonal Claimed Capability Audit every Capability Demonstration Year and a winter Seasonal Claimed Capability Audit at least once in the previous three Capability Demonstration Years to establish summer and winter Seasonal Claimed Capability ratings.See OP-23 Generation Resource Auditing, SOP-OUTSCH 0010.0020 Scheduling Capability, Claim 10_30 and MRR Audits, and CROP.45002 Auditing.22X13.6.2.1.2(b)Submit Operating Data to the app. Information describing the GADS Data collection process can be found at HYPERLINK "http://www.iso-ne.com/genrtion_resrcs/gads/"http://www.iso-ne.com/genrtion_resrcs/gads/. This requirement pertains to all generating Resources including those having no Capacity Supply Obligation.PowerGADS found at  HYPERLINK "https://iso-ne.powergads.com/" https://iso-ne.powergads.com/.2313.6.2.1.2(c)Notify app of planned and maintenance outages.Market Participant must comply with outage scheduling requirements to notify app of planned and maintenance outlined in the app Operating Procedure #5 and app Manuals. Generating Capacity Resources having no Capacity Supply Obligation are not subject to the forced re-scheduling provisions for outages in accordance with the app New England Manuals and app Operating Procedures.Planned outage requests submitted via e-mail to: opamoreq@iso-ne.com. Maintenance outage requests are submitted to the Generation Coordinator at 413-535-4378. 24X13.6.2.3.2(a) 1.5.1Schedule audit to determine capacity rating.See OP-23 Generation Resource Auditing.Contact app Customer Support for additional information.25X13.6.2.3.2(b)Submit Operating Data to the app.Information describing the GADS Data collection process can be found at HYPERLINK "http://www.iso-ne.com/genrtion_resrcs/gads/"http://www.iso-ne.com/genrtion_resrcs/gads/. Information is submitted using PowerGADS found at  HYPERLINK "https://iso-ne.powergads.com/" https://iso-ne.powergads.com/.26X13.6.2.4.2(a) 1.7.11Conduct a summer Seasonal Claimed Capability Audit every Capability Demonstration Year and a winter Seasonal Claimed Capability Audit at least once in the previous three Capability Demonstration Years to establish summer and winter Seasonal Claimed Capability ratings.See OP-23 Generation Resource Auditing, SOP-OUTSCH 0010.0020 Scheduling Capability, Claim 10_30 and MRR Audits, and CROP.45002 Auditing.27X13.6.2.4.2(b)Submit Operating Data to the app.Information describing the GADS Data collection process can be found at HYPERLINK "http://www.iso-ne.com/genrtion_resrcs/gads/"http://www.iso-ne.com/genrtion_resrcs/gads/. Required of Settlement Only Resources.Information is submitted using PowerGADS found at  HYPERLINK "https://iso-ne.powergads.com/" https://iso-ne.powergads.com/.28X13.6.4Reply to the apps request for energy either affirmatively, or negatively.Market Participant to deliver reliability energy in real-time in an amount and duration specified by the app and agreed to by the generating resources Designated Entity.EMS, RT-UDS 2.7 Performance, Payments and Charges Resource TypeMaster Schedule Step/Event IdentifierMarket Rule 1 III Section NumberParticipant ActionDescription of Participant Deliverables/Additional Informationapp System and/or ProcessD RG CI CI P1XXXX13.7Notify the app of a change in ownership of a resource that has a Capacity Supply Obligation.Notify the app of changes in the Lead Market Participant for a Capacity Resource. Contact app Customer Support for additional information. 2X13.7.1.1.3(a)-(h)Submit a resources Economic Maximum Limit. Re-declare a resources Economic Maximum Limit.See the eMkt User Guide at  HYPERLINK "http://www.iso-ne.com/participate/support/user-guides" http://www.iso-ne.com/participate/support/user-guides.Demand Bid and Supply Offer data is submitted to the app using the eMkt system. 3X13.7.1.1.4(b)Indicate on a planned outage request that the outage should be considered exempt from penalties. Upon submittal of the outage request to the app, and at least 15 calendar days prior to the beginning of the outage, indicate the outage should be considered exempt. This will reduce the resources annual and major maintenance period allotment hours. Generating resources: Requests will be made in CROW system or by planned outage requests submitted via e-mail to: opamoreq@iso-ne.com. Import Capacity Resources and Settlement Only Resources: Outage request should be submitted to app Customer Support (custserv@iso-ne.com). The request should include the begin and end dates of the outage, the amount of the outage, and whether it should be considered exempt for FCM availability penalty purposes.4X13.7.1.1.5Submit information demonstrating that the reasons for inadequate availability scores have been remedied by a resource the app has determined is a Poorly Performing Resource. The app will notify Market Participants if their resources are considered to be Poorly Performing Resource. Contact app Customer Support for additional information. 5X13.7.1.2(a)-(b), (d)Submit External Transaction and designation of the MWs associated with that Transaction to the app.See the User Guide for External Transactions Using EES at  HYPERLINK "http://www.iso-ne.com/participate/support/user-guides" http://www.iso-ne.com/participate/support/user-guides. Enhanced Energy Scheduling (EES) system.6X13.7.1.2.1Submit planned outage information to the app. Request can be made by an Import Capacity Resource backed by a single External Resource. The outage must be approved in the apps annual maintenance scheduling process. Requests must include the following information: Asset identification number Outage begin date Outage end date Outage amount, in MW Seasonal Claimed Capability value of the unit backing the Resource In the request, indicate that the outage MWs should be used to increase the resources hourly availability score if a Shortage Event were to occur during the outage period. Request must be submitted no later than 15 calendar days prior to the outage date.Outage requests should be submitted to app Customer Support.7X13.7.1.4.1Meter the output for an hour of a Non-Intermittent Settlement Only Resource. Metering requirements are described in OP 18 - Metering and Telemetering Criteria and Manual 28 Market Rule 1 Accounting. Indicate on a planned outage request that the outage should be considered exempt from penalties. Outage requests must be approved in the apps annual maintenance scheduling process. Requests must include the following information: Asset identification number Outage begin date Outage end date Outage amount, in MW Seasonal Claimed Capability value of the asset Submit planned outage information to the app no later than 15 calendar days prior to the outage date. In the request, indicate that the outage MWs should be used to increase the resources hourly availability score if a Shortage Event were to occur during the outage period.Outage requests from Non-Intermittent Settlement Only Capacity Resources are submitted to app Customer Support.8X13.7.1.5.4 13.7.1.5.5Submit engineering estimates or audit results pursuant to a Measurement and Verification Plan to supplement missing data. Available for Seasonal Peak and On-Peak Demand Resources entering services at a time such that there is incomplete performance data to establish summer or winter seasonal Demand Reduction Values. Measurement and verification procedures are described in the app Manual for Measurement and Verification of Demand Reduction Value from Demand Resources.Contact app Customer Support for additional information. 9X13.7.1.5.5 13.7.1.5.7 13.7.1.5.8Notify the app of election to conduct an audit before the end of a month to establish a Demand Reduction Value for a subsequent month in which there are no event hours. Available for Seasonal Peak Demand Resources, Real-Time Demand Response and Real-Time Emergency Generation Resources. Measurement and verification procedures are described in the app Manual for Measurement and Verification of Demand Reduction Value from Demand Resources.Contact app Customer Support for additional information. 10By 13:00 of the second Business Day after each Operating Day13.7.3Submit a Load Assets peak contribution value for each day of the month.Each Load Assets Assigned Meter Reader is required to submit a peak contribution value for each Operating Day of a Capacity Commitment Period month.Peak contributions are submitted to the Peak Contribution user interface (a SMD Application).1113.7.3As needed, submit percentage ownership changes for Load Assets. As ownership changes for Load Assets, these changes are required to be submitted to the app prior to the effective date of the change. Please contact apps Customer Support department for specific timing of this requirement. Ownership changes for Load Assets must be submitted to Customer Support at custserv@iso-ne.com.1213.7.3As needed, submit percentage entitlement changes for HQ Phase I or II. As entitlement changes for HQ Phase I or II, these changes are required to be submitted to the app 30 days prior to the effective date of the change. Please contact apps Customer Support department for questions about this requirement.HQ Phase I or II entitlement changes must be submitted to Customer Support at custserv@iso-ne.com. Section 3: Requirements Applicable to Dispatchable Asset Related Demands 3.1 Establishing and Adjusting Dispatchable Asset Related Demand Coincident Peak Contribution The Coincident Peak Contribution of a Dispatchable Asset Related Demand is initially set equal to the Nominated Consumption Limit submitted during the Asset Registration Process. The Coincident Peak Contribution reflects the capability of the Dispatchable Asset Related Demand to reduce its consumption to the Nominated Consumption Limit recognizing that the Dispatch Instructions at the time of the yearly coincident peak may require the Dispatchable Asset Related Demand to consume at a level greater than that Nominated Consumption Limit. The Host Participant Assigned Meter Reader submitted Peak Contribution values of Dispatchable Asset Related Demands will be adjusted by the app as follows: (a) Adjustments based on the results of audits (the audit process is described in the app Manual for Registration and Performance Auditing, M-RPA). (b) Adjustments for customer additions or deletions calculated by the Host Participant Assigned Meter Reader as described in Section 3.1.1.2 of this manual. (c) Adjustments for non-conformance with specific Bid and Redeclaration requirements (this adjustment is described in Section 3.1.1.1 of this manual). 3.1.1 Adjustments to Dispatchable Asset Related Demand Peak Coincident Contribution For every hour of any day, the Lead Market Participant associated with a Dispatchable Asset Related Demand must offer a Minimum Consumption Limit that is less than or equal to its Nominated Consumption Limit by submitting a Demand Bid into the Day-Ahead Energy Market. Scheduling and offering procedures are described in the app Manual for Market Operations, M-11. For any hour of any day that the Dispatchable Asset Related Demand cannot reduce to its Minimum Consumption Limit, the Lead Market Participant must notify the app Operations Department through submission of a Redeclaration of Minimum Consumption Limit. Extended process outages associated with Dispatchable Asset Related Demand facilities that would significantly increase the Dispatchable Asset Related Demands Minimum Consumption Limit must be reported to the app in advance according to the procedures described in OP-5 and reflected in the Demand Bid. 3.1.1.1 Dispatchable Asset Related Demand Non-Conforming Demand Bid Adjustment For each Capacity Commitment Period, the app will calculate an adjustment for non-conforming Demand Bids. This evaluation will be performed during Shortage Event hours in the prior Capacity Commitment Period, and will include hours for which a Dispatchable Asset Related Demand submitted, either via its Demand Bids into the Day-Ahead Energy Market or via a Redeclaration in Real-Time, a Minimum Consumption Limit greater than its Nominated Consumption Limit. The adjustment, calculated in MW to three decimal places, will be applied in the calculation of the Dispatchable Asset Related Demands Coincident Peak Contribution values for the Capacity Commitment Period. So as to provide Dispatchable Asset Related Demands some ability to manage constraints for their processes by temporarily redeclaring their Minimum Consumption Limits, an exception will automatically be granted for any hour for which a redeclaration of the Minimum Consumption Limit to a level above the Nominated Consumption Limit is submitted following a Dispatch Instruction to increase consumption. This exemption will be applied to the hour in which the Dispatch Instruction was issued and to all remaining hours of the Operating Day. The Capacity Commitment Period Adjustment MW shall equal the total of all Violation MW divided by the total Shortage Event Hours, where: Violation MW = the sum of (Minimum Consumption Limit Nominated Consumption Limit) for each identified Capacity Commitment Period Shortage Event hour in which a justifiable bidding violation has occurred. 3.1.1.2 Dispatchable Asset Related Demand Metering Adjustment Coincident Peak Contributions are assigned to physical locations, and so contributions may be added or deleted only if a location consuming energy itself is added or eliminated. Movement of customers among existing locations shall not justify an adjustment to Coincident Peak Contributions. If a new load is added, the Host Participant Assigned Meter Reader with responsibility for reporting the load of that premise, meter, or account shall assign a Coincident Peak Contribution value to that premise, meter, or account. The Coincident Peak Contribution assigned will be based on the class average load shape of the relevant load class. In addition, the permanent departure of customer load from the New England Control Area will result in the deletion of the Coincident Peak Contribution value associated with that load. An example of such a permanent departure would be the shutdown and demolition of a factory. To maintain the integrity of the load-shift accounting process, the Host Participant Assigned Meter Reader shall re-scale the Coincident Peak Contributions reported for each Load Asset to maintain the total Coincident Peak Contribution value reported by that Host Participant Assigned Meter Reader for the year. In the event that a net change in position of 10% or more of a Metering Domains contribution to the New England Control Area coincident peak is reached, the Host Participant Assigned Meter Reader shall report such change to the app. If after verification it is determined that the net gain or loss of customers by a Host Participant is 10% or more, the app shall change the Coincident Peak Contribution value to be reported by the Host Participant Assigned Meter Reader, as well as changing the denominator of the system-wide allocation equation. The impact of these adjustments is to reallocate the net gain or loss of load within a particular Metering Domain to the New England Control Area as a whole. To remain equitable with other load types, Dispatchable Asset Related Demand Resources will be subject to such adjustments and the value of these adjustments will be added to the Resources Nominated Consumption Limit during the calculations of the capacity obligation. For each month of each Capacity Commitment Period, the app will calculate a metering adjustment for Dispatchable Asset Related Demand Resources based on the following two values: (a) The registered value of the historic Coincident Peak Contribution. This value is included with asset registration information provided to the app and is referred to in the Asset registration/change form as the Baseline Pool Peak Contribution MW. (b) The submitted values of daily Coincident Peak Contributions, otherwise known as daily tags as provided by the Host Participant Assigned Meter Reader. The monthly metering adjustment described above will be calculated in MW to three decimal places as follows: Metering Adjustment = the average of the daily Coincident Peak Contribution for days the Resource is active plus the registered value of the Resources Baseline Pool Peak Contribution MW. Attachment A: Reserved Attachment B: Reserved Attachment C: Host Participant Assigned Meter Reader Requirements The following describes the Host Participant Assigned Meter Readers procedures for determining and reporting to the app, each Load Asset identification number share of the daily Coincident Peak Contribution, with the exception of loads that are assigned a Coincident Peak Contribution of zero for the purposes of assigning obligations and tracking load shifts as described in Section III.13.7.3.1 of Market Rule 1, for which the Host Participant Assigned Meter Reader has meter reading responsibility. The Host Participant Assigned Meter Reader shall: (1) Determine each individual customers contribution to peak load, using the utility specific customer identifier(s) such as premise, meter, or account number. (a) The customers contribution to peak load shall reflect the hourly integrated electric consumption, on the peak day and hour as specified by app, adjusted for losses and unaccounted for energy below the PTF. (i) If hourly interval billing metered data was used for load estimation and reporting to app, the individual customers contribution to peak load should be based upon the hourly metered usage. (ii) If hourly interval billing metered data was not used for load estimation and reporting to the app, the individual customers contribution to peak load shall be based upon the hourly estimated value determined using the relevant retail regulatory authoritys customer load profiling techniques. (2) The aggregation of individual customers by Load Asset that is used for the settlement reporting to app for the Energy Market shall also be used to aggregate the individual customers contribution to coincident peak load (plus losses and unaccounted for energy). This aggregated value will be the Load Assets Coincident Peak Contribution. (3) The Host Participant Assigned Meter Reader will report to the app, for each registered Load Asset within the metering domain, each Load Assets Coincident Peak Contribution value, in MW to three decimal places. The sum of all the Load Assets being reported by each Host Participant Assigned Meter Reader will equal the total metering domains Coincident Peak Contribution for each settlement day. (4) The individual Load Assets Coincident Peak Contribution value within a metering domain will be scaled to reflect customer additions and deletions that occur within the metering domain during the Capacity Commitment Period. The individual customers contribution(s) to peak load value shall be used to assign capacity obligations for the Capacity Commitment Period. (5) If the coincident peak load details (i.e. date, hour end, and total load by Meter Domain) reported by the app are preliminary then, instead of determining each individual customers contribution to peak load, the Host Participant Assigned Meter Reader may determine Coincident Peak Contribution values at the Load Asset level. Changes to individual Load Asset Coincident Peak Contribution values may be submitted to the app for the Data Reconciliation Process and the Meter Data Error correction request process, as appropriate. Changes to individual Load Asset Coincident Peak Contribution values resulting from final coincident peak load details reported by the app shall be submitted to the app for the Data Reconciliation Process and the Meter Data Error Correction request process, as appropriate. Attachment D: Reserved Attachment E: Reserved Attachment F: Reserved Attachment G: Reserved Attachment H: Reserved Attachment I: Northeast MOU General ICAP Principles The following are the external ICAP provisions from the Northeast Memorandum of Understanding between PJM, New York and New England. Considerations and Requirements for External ICAP Transactions These general principles establish a common understanding for ICAP products transacted (purchase/sale) across Control Area boundaries for the ICAP markets established b the app, NYapp and PJM. Planning Principles I. The minimum duration for the transaction must be the minimum duration required for a purchase by the market rules of the Operating Jurisdiction of the purchasing entity. II. The buyer/seller must demonstrate/verify to their appropriate Operating Jurisdictions that the ICAP resource is not committed to or sold to more than one Operating Jurisdiction. III. Delivery of the ICAP energy cannot be subject to frequent and routine curtailment due to transmission constraints. Therefore, to reasonably ensure deliverability when called upon, the following are required for ICAP recognition: a) firm transmission service or equivalent delivery guarantee to the sink Operating Jurisdictions border across restricted or congested external transmission. This means that curtailment for transmission security is done in accordance with the applicable tariffs on a comparable basis with other firm customers, including firm load (see Curtailment Principles for details). b) deliverability within the sink Operating Jurisdiction must meet the requirements of that system and should be consistent with the deliverability requirements of internal generators. Scheduling Principles I. When scheduled, the energy associated with the ICAP purchase must be backed by operating capacity. "Backed by operating capacity" will mean that the source Operating Jurisdiction is committing generating capacity to provide for the transaction. The source or any intervening Operating Jurisdictions cannot count the scheduled energy as operating reserve and cannot curtail the transaction as a result of loss of resource contingencies on their systems (except as allowed under Curtailment Principle I b and I c on the source system only). II. The energy associated with an ICAP contract must be schedulable on at least a daily basis provided any unit specific resource is not on a recognized outage. III. The ICAP and associated energy must be a bundled resource (i.e. the energy bids associated with a specified resource must be bid according to the sink Operating Jurisdictions market rules). This does not preclude a system ICAP contract provided: a) the ICAP and associated energy are from the same jurisdiction and same seller. such a sale is allowed by the market rules of the source and sink jurisdictions. c) all applicable requirements of the source, intermediate and sink Operating Jurisdictions are satisfied by the seller and buyer. Current Day Call Principles I. When experiencing a capacity shortage, the sink Operating Jurisdiction has first call rights in accordance with their market requirements, to the energy that is being produced or could be produced by the ICAP resource, whether or not the energy had been previously scheduled by the buyer. II. The ICAP supplier is obligated to provide available energy in accordance with the sink Operating Jurisdictions market rules Curtailment Principles I. When a sink Operating Jurisdiction has exercised its rights to the capacity and energy associated with an ICAP transaction, the transaction can only be curtailed for the following conditions on the source and external intervening systems: a) to correct or prevent a violation of voltage, stability, or thermal transmission limits / criteria in accordance with transmission tariffs for the level of transmission service associated with the ICAP contract. b) for an ICAP contract that is resource specific, temporary unavailability of the resource on which the contract is based. c) for a system contract (as allowed under Scheduling Principle IIIb), which is backed by all the resources in the source system, the capacity and energy may be curtailed by the source Operating Jurisdiction for capacity and energy shortage conditions on a pro-rata basis and concurrent with the shedding of source systems firm load. This means the energy associated with an ICAP transaction cannot be curtailed as a result of, or to avoid the following conditions on the source or intervening Operating Jurisdictions system: a) capacity shortage conditions resulting in the implementation of voltage reduction and/or load shedding, except as provided for a system contract above. b) generator losses other than the identified source specific resource associated with the ICAP transaction. Attachment J: Reserved Attachment K: Maintenance Allotment Hours A Resources hourly availability score may be increased when an Asset associated with the Resource is on a planned outage. Market Participants may indicate when submitting a planned outage request in accordance with app Operating Procedure No. 5 that the outage is to be considered exempt. In such cases the associated Resources hourly available MWs may be increased by an amount up to the outage MWs requested, provided that the Resource has not exceeded the maintenance allotment hour limits regarding exempt approved planned outages at the time of the Shortage Event as described in Table K-1 below, and subject to the other provisions and conditions below. Equivalent Planned Outage Hours For each hour of a planned outage for which a Resource has requested exemption, the app will calculate an Equivalent Planned Outage Hour as shown below. EPOH = Eligible MWs / CSO where: EPOH = Equivalent Planned Outage Hour CSO = the resources Capacity Supply Obligation Eligible MWs = the MW increase to a resources hourly available MWs, equal to: Eligible MWs = max (min (MWsrequested, CSO max (SCC MWsrequested, 0)),0) where: MWsrequested = the asset MWs requested in the planned outage submittal SCC = the assets applicable Seasonal Claimed Capability at the beginning of the planned outage, and the SCC at the beginning of each month during the outage The calculation of Equivalent Planned Outage Hours will begin at the later of either the approved planned outage start time or the actual planned outage start time, and end at the earlier of either the approved planned outage end time or the actual planned outage end time. For these purposes the actual start of a planned outage will be when the app issues a Dispatch Instruction for the Asset to shutdown or otherwise acknowledges that the Asset is henceforth unavailable for dispatch per the scheduled planned outage. The actual end time of a planned outage will be when the Asset is released to the app for commitment or dispatch instructions. As of June 1, 2010 the cumulative Equivalent Planned Outage Hours for all Resources shall be zero. If the app delays a request to shutdown an Asset or otherwise delays a request to begin a planned outage per the scheduled and approved outage start time and date, the Eligible MWs related to the planned outage will be used to adjust the Resources hourly availability score if a Shortage Event occurs after the scheduled start time and date but before the actual outage start time and date. In such cases, the Eligible MWs of the planned outage would likewise be used to adjust the hourly availability score of the Resource if a Shortage Event occurs after the scheduled end time and date but before a period has elapsed equal to the time between the scheduled outage start time and date and the actual start time and date. Maintenance Allotment Hours During qualification, each Generating Capacity Resource will be assigned to one of the types listed in Table K-1. For each generator type, a Maximum Exempt Planned Maintenance Hours per Capacity Commitment Period limit, a Major Maintenance Period in years, and a Maximum Equivalent Planned Maintenance Hours per Major Maintenance Period is specified. Maximum Exempt Planned Maintenance Hours per Capacity Commitment Period is the maximum number of Equivalent Planned Outage Hours that may be used to adjust the Resources hourly available MWs in any single Capacity Commitment Period. Maximum Equivalent Planned Maintenance Hours per Major Maintenance Period is the maximum number of Equivalent Planned Outage Hours that may be used to adjust the resources hourly available MWs over the corresponding Major Maintenance Period. Major Maintenance Period is a rolling number of Capacity Commitment Periods over which the resource is limited to the Maximum Equivalent Planned Maintenance Hours per Major Maintenance Period. Exemption Where a Resource is on a planned outage and has requested exemption, the resources hourly availability score will be increased by an amount equal to the Eligible MWs as calculated above, provided that the Resource has not exceeded the maximum maintenance allotment hour limit regarding exempt approved planned outages at the time of the Shortage Event as described below. In the case of a Settlement Only Resource, a planned outage scheduled in either December or January or during the period June 1 through September 15 may not be used to increase the Resources hourly availability score. The hourly available MW adjustment will be made based on Eligible MWs, provided the following are both true: (1) The Resources cumulative Equivalent Planned Outage Hours in the current Capacity Commitment Period do not exceed the Resources Maximum Exempt Planned Maintenance Hours per Capacity Commitment Period. (2) The Resources cumulative Equivalent Planned Outage Hours over a period equaling the Resources Major Maintenance Period (which shall include the current Capacity Commitment Period) do not exceed the Resources Maximum Equivalent Planned Maintenance Hours per Major Maintenance Period. If during a Capacity Commitment Period either condition becomes false, all subsequent Equivalent Planned Outage Hour values will be set to zero for the remainder of the Capacity Commitment Period. Table K-1 Generator Maintenance CategoryMaximum Exempt Planned Maintenance Hours per Major Maintenance Period Major Maintenance Period (Years)Maximum Exempt Planned Maintenance Hours per Capacity Commitment Period Coal Fired Steam Plant Subcritical7,20091,400Coal Fired Steam Plant Supercritical and Cyclone Boilers8,40091,700Oil and Dual-fired Steam Plant - Subcritical6,50091,400Oil and Dual-fired Steam Plant - Supercritical7,70091,700Natural Gas Fired Steam Plant6,50091,400Waste Fuel Fired Steam Plant6,50091,400Combined Cycle Combustion Turbine Plant5,00091,400Natural Gas Simple Cycle Turbine Plant1,20031,000Jet Fuel Fired Simple Cycle Turbine Plant1,20031,000Oil Fired Simple Cycle Turbine Plant1,70031,100Internal Combustion Engine Plant1,60031,100Nuclear Power Plant2,50031,400Hydro Power Plant6,900102,000Pumped Storage Power Plant6,900102,000 The app will present to stakeholders a review of the values in this table at least once every five years. Attachment L: Reserved Attachment M: New Import Capacity Resource Qualification Information Form  app (app-NE) Forward Capacity Market New Import Capacity Resource Qualification Information Form Revised: July 31, 2013  app (app-NE) Forward Capacity Market New Import Capacity Resource Qualification Information Form One form must be completed for each generator supporting the New Import Capacity Resource being proposed to qualify to participate in a Forward Capacity Auction (FCA). In accordance with Section III.13.1.1.2.7. which grants the app the authority to gather all necessary information, failure to provide adequate information sufficient to establish the ability of the generator to deliver capacity to New England will result in Resource Disqualification for the relevant Capacity Commitment Period. Generator Name: __________________________________________________ Provide the Station Name that the generator is associated with if the generator is a part of a multi-unit generating station: ________________________________________________________________ Provide the control area in which the generator is interconnected: ________________________________________________________________ (If applicable) Provide the unique identifier for the generator utilized by the control area in which the generator is interconnected: ________________________________________________________________ Is there a capacity market in the control area in which this generator is interconnected? Yes No If yes, provide the following: Provide documentation for the generators approved maximum interconnection limit amount in the native control area. Provide documentation for the last five years identifying the MW amount that the generator was/would have been approved to provide as capacity by the control area in which it is interconnected. Is the generator, or will the generator be, obligated to provide capacity to the control area in which it is interconnected or to a control area other than app-NE for the relevant Capacity Commitment Period? If so, which control area and how many MWs are required to be provided? Provide the app FCM Resource Name and Resource ID that this generator part of: ________________________________________________________________ New Qualification Additional Import Information Form Page 3 of 9 July 31, 2013 2013 app. Generator Type(s): Hydraulic Turbine Conv Daily RORHydraulic Turbine Conv Daily PondageCombined Cycle Total UnitCompressed Air Energy StorageFuel Cell ElectrochemicalCombustion (Gas) TurbineHydraulic Turbine PipelineInternal Combustion EngineIntegrated Coal Gasification Comb CyclePressurized Fluidized Bed CombustionHydraulic Turbine ReversiblePhotovoltaic (solar)Steam TurbineWind TurbineHydraulic Turbine Conv Weekly Pondage Run of River HydroUnknown at this TimeOther ____________________________________________________________________________________________________________________________________________________________________________________________________________________ Energy Source(s): Anthracite Coal and Bituminous Coal Residual Fuel Oil No. 6 020 Agricultural Crop Byproducts/Straw/Energy Crops Coal Synfuel. Blast Furnace Gas Sludge Waste Black Liquor Subbituminous Coal Distillate Fuel Oil. Including Diesel, No. 1 Solar Distillate Fuel Oil. Including Diesel, No. 2 Tire-derived Fuels Distillate Fuel Oil. Including Diesel, No. 4 Water at a Conventional Hydroelectric Turbine Jet Fuel Waste/Other Coal. Kerosene Wood Waste Liquids excluding Black Liquor. Landfill Gas Wood/Wood Waste Solids. Lignite Coal Wind Municipal Solid Waste Waste/Other Oil. Natural Gas Distillate Fuel Oil. Including Diesel, No. 3 Nuclear Uranium, Plutonium, Thorium Distillate Fuel Oil No. 5 Other Biomass Gas. Includes digester gas, methane, and other biomass gasses. Liquefied Propane, No. 3 Other Biomass Liquids. Multifuel Other Biomass Solids Gasoline, Conventional Petroleum Coke Gasoline, Reformed Gaseous Propane Gasoline, Ethanol Purchased Steam Gasoline, Oxygenated Residual Fuel Oil Bunker C Gasoline Other (explain in detail the characteristics) ______________________ ______________________ ______________________ New Qualification Additional Import Information Form Page 5 of 9 July 31, 2013 2013 app. Describe the generation classification in the control area in which it is interconnected. For example, a run of river hydro electrical generator that does not have control over its water would be considered intermittent in the New England control area in accordance with Section III.13.1.2.2.2 of the app-NE Tariff. Cite supporting documentation to verify classification. Is the generator able to respond to its control area dispatch instructions output over full operating range? Yes No If no, describe any limitations to respond to these control area dispatch instructions? _________________________________________________________________________________________________________________________________________________________________________________ Does the generator meet the app-NE definition of a Limited Energy Generator? (app-NE defines a Limited Energy Generator as a generator that, due to design considerations, environmental restriction on operations, cyclical requirements, such as the need to recharge or refill or manage water flow, or fuel limitations, is unable to operate continuously at full output on a daily basis). Yes No Is the generator a solar, wind, run of river hydro or does the net power output of the generator have variability that is beyond the control of the facility owner or operator during any of the following periods: June-September: during hours ending 1400-1800; and October-May: during hours ending 1800-1900 Yes No New Qualification Additional Import Information Form Page 6 of 9 July 31, 2013 2013 app. For any generator answering yes to questions 9b or 9c, provide the actual median MW value of the proposed generators output for each of the last five years, during the hours described in question 9c. YearJune-September Actual Median MWs during hours ending 1400-1800October-May Actual Median MWs during hours ending 1800-1900 For generators with a capacity market in the control area in which they are interconnected, provide the capacity rating for the past five years. For generators interconnected to a control area without a capacity market provide the audit (demonstrated maximum) MW rating for the generator for the last 5 years during the summer period (June-September) and the winter period (October-May). YearSummer Audit Value MWs (June-September)Winter Audit ValueMWs October-May) Explain in detail the process, and commercial arrangement, by with the capacity and associated energy from the proposed generator will be deliverable to the New England control area border, on the peak design day of the control area to which the generator is interconnected and any intervening control areas through which the proposed capacity may be wheeled. Provide detail how the capacity and associated energy will be recognized by the control area to which the generator is interconnected with the same priority as native load. New Qualification Additional Import Information Form Page 7 of 9 July 31, 2013 2013 app. Per the ICAP Memorandum Of Understanding (MOU) Curtailment Principal 1.a, the control area to which the generator is interconnected and any intervening control areas through which the capacity may be wheeled is not required to deliver the energy associated with capacity if there is a transmission constraint that is located between the capacity generator and the external interface that is at or approaching a violation, and the flow from that generator to the external interface has a direct impact on that constraint. As such, for generators interconnected to control areas that are signatory to the aforementioned ICAP MOU describe any internal transmission constraints that could prevent the capacity and/or energy [as appropriate] from this generator from being delivered to the app-NE control area with a priority equal to native load in the control area in which the generator is interconnected Cite both on peak and off peak periods that relevant transmission constraints would impact the ability of the capacity and/or the energy to reach the New England Border. For each constraint cited, provide documentation shared with NERC Reliability Coordinator as well as documentation (e.g., manuals, tariff language, and operating documents) that support capacity-backed energy transaction during periods when relevant constraints are binding. In addition to app-NE and the originating control area, will the proposed generator be wheeled thru any other control area? Yes No If yes and for each control area through which the proposed capacity transaction is wheeled, provide documentation that the wheeled through control area(s) allows [recognizes] a capacity transaction to be wheeled through its area. If yes, describe the process(es) used in the [wheeled through] control area to match the import of capacity to the export of capacity during daily operation to ensure the [capacity and associated] energy that is received at one border is delivered and credited to the receiving control area with a priority equal to that of native load. For any import and export interface [in the wheeled through control area ]associated with a wheel through of capacity and associated energy provide the MW interface (long-term emergency) limit, and provide any MW portion of the limit preferentially allocated for delivery to native load in the control area. Note: For the purposes of completing Questions 14a, b, and c, it is not sufficient to identify procedures that permit the wheeling of non-firm energy during daily operation. In answering this question, a capacity wheel would be defined as a capacity transaction that treats the import side of the wheel the same as it would treat an operating physical generator interconnected at the import point. For proposed generators that must be wheeled-through an adjacent control area before reaching the New England border, describe any and all transmission constraints that may prevent the capacity and/or energy [as appropriate] from being delivered to the app-NE control area. New Qualification Additional Import Information Form Page 9 of 9 July 31, 2013 2013 app. Revision History Approval Approval Date: May 7, 2010 Effective Date: June 1, 2010 Revision History Revision: 1 - Approval Date: November 18, 2010 Section No. Revision Summary 2.4 (Row 2) Revises the Participant Action section to include the submittal of a written plan describing the measures that will be taken to address the reduction if applicable. 2.4 (Row 2a)... Adds a new Row 2a to the Market Participant Action Matrix regarding the Reconfiguration Auction. Attachment C. Adds a new Attachment C titled Host Participant Assigned Meter Reader Requirments. Attachment G. Deletes the previous Attachment G titled Data Requirement Matrix for Demand Resources and reserves this attachment for future use. Revision: 2 - Approval Date: March 4, 2011 Section No. Revision Summary 1 (Attachment A Master FCM Schedule) Step/Event Identifier: A-2..Revises Show of Interest (Start) dates for FCA6, FCA7 and FCA8. A-3..Revises Show of Interest (End) date for FCA8. A-4..Revises Qualification Review Begin date for FCA8. A-7..Revises app publishes Dispatch Zones dates for FCA6, FCA7 and FCA8. Revision: 3 - Approval Date: April 1, 2011 Section No. Revision Summary 2.1 (Market Rule 1 Section Number 13.1.4.1.1) Revises reference from app Manual M-28 to app Manual M-RPA. Revision: 4 - Approval Date: February 4, 2011 Section No. Revision Summary Attachment K. Adds a new Attachment K titled Maintenance Allotment Hours. Revision: 5 - Approval Date: June 10, 2011 Section No. Revision Summary 2.1 (Market Rule 1 Section Number 13.1.9.3) ....Revises Master Schedule Identifier from 10 days after invoice to As invoiced and adds that the payment terms follow the app Billing Policy under the Additional Information column of the matrix. 2.1 (Market Rule 1 Section Number 13.1.9.3.1) Deletes the two references to requesting a waiver of a portion of the Qualification Process Cost Reimbursement Deposit for a project that has an active Interconnection Agreement and for a New Demand Resource under the Participant Action column of the matrix. 2.5 (Market Rule 1 Section Number 13.5.3.2.1) Adds the ability to include a Supplemental Availability Bilateral Contract in the initial settlement at a deadline later than 12:00 pm on the second Business Day after the end of the obligation month if specified by the app upon notice to Market Participants and revises the deadline for confirming, modifying or terminating a Supplemental Availability Bilateral Contract. 2.6 (Market Rule 1 Section Number 13.6.1.2.2(d)) Adds a requirement to provide for each External Transaction a reference to the associated Import Capacity Resource under the Participant Action column of the matrix and to contact app-NE Customer Support for additional information under the app System and/or Process column of the matrix. Revision: 6 - Approval Date: August 12, 2011 Section No. Revision Summary 1 (Attachment A Master FCM Schedule) Step/Event Identifier: A-12... Deletes the phrase and Op Cap Analysis from the step description. A-20Revises the step to insert DRV based on apps most recent between Submits and Op Cap Analysis. 2.6 (Row 3, Market Rule 1 Section Number 13.6.1.1.3) Deletes this row in its entirety. Revision: 7 - Approval Date: January 20, 2012 Section No. Revision Summary 3.1...Changes singular uses of customer to Dispatchable Asset Related Demand. Revision: 8 - Approval Date: March 9, 2012 and June 1, 2012 Section No. Revision Summary 2.5 (Market Rule 1 Section Numbers 13.5.3.1 and 13.5.3.2) Deletes the sentence The Supplemental and Supplemented Capacity Resources must be in the same Reserve Zones. from the Description of Participant Deliverables/Additional Information column. This set of revisions was approved on June 1, 2012 1 (Attachment A Master FCM Schedule) Step/Event Identifier: A4... Deletes this item in its entirety. A16. Deletes the word includes. A20. Spells out Lead Market Participant and deletes reference to the OpCap Analysis. A29. Revises the FCA7 and FCA8 dates. A34. Revises the FCA3, FCA4 and FCA5 dates and adds the FCA6, FCA7 and FCA8 dates. A36. Revises the FCA3, FCA4, FCA5, FCA6, FCA7 and FCA8 dates. 2.1 (Market Rule 1 Section Number 13.1.4.3.1.3) ... Revises the description of the treatment Real-Time Demand Response Resources and Real-Time Emergency Generation Resources. 2.1 (Market Rule 1 Section Number 13.1.4.3.1.3.1) ... Deletes the reference to Appendix D and corrects the reference to Manual M-RPA. 2.1 (Market Rule 1 Section Numbers 13.1.4.5.1 and 13.1.4.5.2) ... Replaces references to Customer Baseline with Demand Response Baseline. 2.1 (Market Rule 1 Section Number 13.1.4.8) ... Deletes this section in its entirety. 2.1 (Market Rule 1 Section Number 13.1.8) ... Deletes Master Scheduler Identifier values A17, A21 and A25. 2.6 (Market Rule 1 Section Number 13.6.1.5.4) ... Adds a new Market Participant Action identified in Section III.13.6.1.5.4 of Market Rule 1. Revision: 9 - Approval Date: June 26, 2012 Section No. Revision Summary 1 (Attachment A Master FCM Schedule) Step/Event Identifier: A17, A21 and A25. Replaces the FCA7 and FCA8 dates with the phrase 15 days after the FCA is conducted. Revision: 10 - Approval Date: June 7, 2013 Section No. Revision Summary Attachment L. Adds a new Attachment L titled Temporary Provisions for Qualification and Related Items for Full Integration of Demand Resources. Revision: 11 - Approval Date: November 2, 2012 Section No. Revision Summary 2.1 (Market Rule 1 Section Number 13.1.4.5.1) ... Replaces Appendix G with app Manual M-28. 2.1 (Market Rule 1 Section Number 13.1.4.5.2) ... Replaces Appendix G with app Manual M-28. 2.2 (Market Rule 1 Section Number 13.2.5.2.5.1(c)(i)) ... Revises the phrase (i) in the same manner as other listed capacity resources, to read (in the same manner as resources with Capacity Supply Obligations,. 2.2 (Market Rule 1 Section Number 13.2.5.2.5.3(a)(iii)) ... Deletes the second sentence. Attachment C (4) ... Replaces Capability Year with Capacity Commitment Period in the second sentence. Revision: 12 - Approval Date: Addressed at the August 2, 2013 Participants Committee meeting Section No. Revision Summary 2.1 (Market Rule 1 Section Number 13.1.3.5.2) ... Replaces the existing language with a reference to the new Attachment M regarding the FCA questions for New Import Capacity Resource qualification and a reference to Section III.13.1.1.2.7 to Market Rule 1. Attachment M ... Adds a new Attachment M titled New Import Capacity Resource Qualification Information Form. Revision: 13 - Approval Date: November 8, 2013 Section No. Revision Summary Throughout the Forward Capacity Market Manual Updates defined terms consistent with Section I.2.2 of the Tariff and makes minor grammatical changes. 1. Removes expiring FCA 3 through FCA 8 dates and inserts cross reference to both FCM Auction calendars on the web and FCTS. 1 (Step/Event Identifiers A5 and A20) ... Deletes step to correspond with Section III.13.1.4.8 deletion from Market Rule 1. 1 (Step/Event Identifier A12) ... Updates Market Rule 1 cross reference to reflect deletion of Section III.13.1.4.8 from Market Rule 1. 1 (Step/Event Identifier A24.1) ... Adds new Step A24.1 consistent with Market Rule 1, Section III.13.1.2.3.2.1.1.2. 1 (Step/Event Identifier A36) ... Updates Market Rule 1 cross reference. 2.1 (Market Rule 1, Section III.13.1.1.2.2.3(a)) ... Replaces two instances of .75 CONE with the relevant Offer Review Trigger Price. 2.1 (Market Rule 1, Sections III.13.1.1.2.2.3 and III.A.21.2) ... Updates Market Rule 1 cross references and adds new language to state that the provision applies only to those requesting to submit offer below the relevant Offer Review Trigger Price. 2.1 (Market Rule 1, Section III.13.1.2.3.1.1) ... Replaces 0.8 times CONE with $1.00 kW/month and adds Market Participant deliverable to notify app regarding participation in energy and ancillary services markets. 2.1 (Market Rule 1, Section III.13.1.2.3.1.2) ... Adds Market Participant deliverable to notify app regarding participation in energy and ancillary services markets. 2.1 (Market Rule 1, Section III.13.1.2.3.2.1.1.2) ... Adds row associated with new Step A24.1 to withdraw or revise a Static De-List Bid where applicable. 2.1 (Market Rule 1, Section III.13.1.3.5.6.2) ... Deletes row to correspond with Section III.13.1.3.5.6.2 deletion from Market Rule 1. 2.1 (Market Rule 1, Sections III.13.1.4.2 and III.13.1.4.2(a)) ... Adds requirement to submit project description form with SOI and adds link to the form. 2.1 (Market Rule 1, Section III.13.1.4.2.2.1) ... Deletes row to correspond with Section III.13.1.4.2.2.1 deletion from Market Rule 1. 2.1 (Market Rule 1, Section III.13.1.4.2.2.2) ... Adds link to credit application and updates system for submission. 2.1 (Market Rule 1, Section III.13.1.4.2.4(b)) ... Deletes information to correspond with Section III.13.1.4.2.4(b) deletion from Market Rule 1. 2.1 (Market Rule 1, Sections III.13.1.4.2.4 and III.A.21) ... Updates cross references and requires supporting documentation for certain offers. 2.1 (Market Rule 1, Section III.13.1.4.3.1.2.1) ... Adds e-mail address for submission. 2.1 (Market Rule 1, Sections III.13.1.4.8.1 and III.13.1.4.8.2) ... Deletes rows to correspond with Section III.13.1.4.8 deletion from Market Rule 1. 2.1 (Market Rule 1, Section III.13.1.5.A ... Deletes notification via priority mail. 2.1 (Market Rule 1, Section III.13.1.9.3.1) ... Updates department contact for app. 2.2 (Market Rule 1, Sections III.13.2.5.2.5.3(a)(ii), (b)(i) and (c)) ... Deletes proration details. 2.4 (Market Rule 1, Section III.13.4.2.1.3(c)) ... Updates reference to 2*CONE to Forward Capacity Auction Starting Price. 2.6 (Market Rule 1, Sections III.13.6.1.1.5(a), III.13.6.2.1.2(a), III.13.6.2.4.2(a) and III.1.7.11) ... Updates auditing requirements and deletes reference to M-RPA and updates to OP-23 reference. 2.6 (Market Rule 1, Sections III.13.6.1.1.5(b), III.13.6.1.3.3.(b), III.13.6.1.4.2(b), III.13.6.2.1.2(b), III.13.6.2.3.2(b) and III.13.6.2.4.2(b)) ... Updates GADs NxL system to PowerGADS. 2.6 (Market Rule 1, Section III.13.6.1.2.1) ... Fixes hyperlink. 2.6 (Market Rule 1, Sections III.13.6.2.3.2(a) and III.1.5.1) ... Updates auditing requirements and deletes reference to M-RPA and updates to OP-23 reference. 2.7 (Market Rule 1, Section III.13.7.1.1.3(i)) ... Deletes auditing provision details based on Market Rule 1, Section III.13.7.1.1.3(i). Attachment L ... Adds new dates consistent with Market Rule 1, Section III.13.1.2.3.2.1.1.2. Revision: 14 - Approval Date: November 2, 2012 Section No. Revision Summary 2.5 (Market Rule 1, Sections III.13.5.1 and III.13.5.1.1.1) ... Revises the two sections to incorporate the enhancements to the Capacity Supply Obligation Bilateral process. Revision: 15 - Approval Date: May 3, 2013 Section No. Revision Summary Attachment C (4) ... Replaces Capability Year with Capacity Commitment Period in the first sentence. Attachment C (5) ... Adds the ability of the Host Participant Assigned Meter Reader to determine Coincident Peak Contribution values at the Load Asset Level if the coincident peak load details reported by the app are preliminary. Attachment C ... Adds a final sentence to this Attachment to have changes to individual Load Asset Coincident Peak Contribution values resulting from final coincident peak load details reported by the app submitted to the app for the Data Reconciliation Process and the Meter Data Error Correction request process, as appropriate. Revision: 16 - Approval Date: May 2, 2014 Section No. Revision Summary 2.1 (Market Rule 1, Section 13.1.2.3.1.5) ....Updates the section to state that a sample Non-Price Retirement Request form is available in Appendix B of Planning Procedure No. 10 and a Non-Price Retirement Request is submitted to the app by using the Forward Capacity Tracking System. 2.2 (Market Rule 1, Sections III.13.2.5.2.5.3(a)(iii), (b)(i) and (c)) Replaces ~6 months after A35 with No later than 15 days before A35. Revision: 17 - Approval Date: November 7, 2014 Section No. Revision Summary 2.5 (Market Rule 1, Section 13.5.3) ....Revises the section to state a Supplemental Capacity Resource designation can occur by the deadline for submission of Supply Offers in the Day-Ahead Energy Market as described in Market Rule 1 Section III,13.5.3 and clarifies that a Supplemental Availability Bilateral may be entered after an Operating Day during which a Shortage Event occurred. 2.6 (Market Rule 1, Sections III.13.6.1.1.1, III.13.6.1.1.2, III.13.6.1.3.1, III.13.6.2.1.1.1) ... Deletes the phrase and Manual 11 Section 8. 2.6 (Market Rule 1, Section III.13.6.2.1.1.1) ... Deletes the last two paragraphs regarding Self-Scheduling actions. 2.7 (Market Rule 1, Section III.13.7.1.1.3(a)-(h) ... Deletes the phrase and Manual 11 Section 8. 3.1.1.1 Deletes the phrase minimum run time. Revision: 18 - Approval Date: October 3, 2014 Section No. Revision Summary 2.1 (Market Rule 1, Section 13.1.5, Resource Type: IP) ....Deletes bullet stating Import Capacity Resources cannot pair with other Import Capacity Resources unless they are on the same interface. 2.5 (Market Rule 1, Section III.13.5.1) Deletes the first two paragraphs to allow for bidirectional trading of CSO bilaterals between Capacity Zones. Revision: 19 - Approval Date: January 9, 2015 Section No. Revision Summary 1. Adds the phrase FCM page by searching for FCM Auction Calendars under Document Type. 2.1 (Market Rule 1, Section III.13.1.1) ....Deletes this Section in its entirety. 2.1 (Market Rule 1, Section III.13.1.1.2.2.4) Adds a new Market Participant Action in Section III.13.1.1.2.2.4 of Market Rule 1. 2.1 (Market Rule 1, Section III.13.1.1.2.9) Adds a new Market Participant Action in Section III.13.1.1.2.9 of Market Rule 1. 2.1 (Market Rule 1, Section III.13.1.2.2.4) Replaces the Market Participant Action in (b) with (Reserved). 2.1 (Market Rule 1, Section III.13.1.2.2.5.2) Revises the Market Participant Action to allow a resources FCA Qualified Capacity to be administratively set by the app and deletes the de-list bid submittal. 2.1 (Market Rule 1, Section III.13.1.2.3) Adds summer or winter prior to Qualified Capacity. 2.1 (Market Rule 1, Section III.13.1.2.3.1.1) Replaces $1.00 kW/month with the Dynamic De-List Bid Threshold and replaces the app website address for the de-list workbook location. 2.1 (Market Rule 1, Section III.13.1.2.3.1.2) Adds the phrase For a Permanent De-List Bid at a price greater than the Dynamic De-List Bid Threshold and replaces the app website address for the de-list workbook location. 2.1 (Market Rule 1, Section III.13.1.2.3.2.1.2) Deletes risk-adjusted from this sentence and replaces the previous process located under app System and/or Process with the current process. 2.1 (Market Rule 1, Section III.13.1.2.3.2.1.2) ....Deletes two Market Participant actions within this Section referencing net risk-adjusted going forward costs. 2.1 (Market Rule 1, Section III.13.1.2.3.2.1.2) ....Deletes risk-adjusted from this sentence and replaces the email address. 2.1 (Market Rule 1, Section III.13.1.2.3.2.1.3) Adds a new Market Participant Action in Section III.13.1.2.3.2.1.3 of Market Rule 1. 2.1 (Market Rule 1, Section III.13.1.2.3.2.1.4) Adds a new Market Participant Action in Section III.13.1.2.3.2.1.4 of Market Rule 1. 2.1 (Market Rule 1, Section III.13.1.2.3.2.1.5) Revises the Market Rule 1 Section from III.13.1.2.3.2.1.3 to III.13.1.2.3.2.1.5. 2.1 (Market Rule 1, Section III.13.1.4.1.2.1) Replaces the app website address for the Measurement and Verification Plan form location. 2.1 (Market Rule 1, Sections III.13.1.4.2 and III.1.4.2(a)) Replaces the app website address for the project description form location. 2.1 (Market Rule 1, Section III.13.1.4.2.2.2) Replaces the app website address for the credit application location. 2.1 (Market Rule 1, Section III.13.1.4.2.2.3) Replaces the app website address for the Measurement and Verification Plan form location. 2.1 (Market Rule 1, Section III.13.1.4.2.5.2) Adds summer or winter prior to Demand Reduction Value. 2.1 (Market Rule 1, Section III.13.1.4.3.1.2) Replaces the app website address for the Measurement and Verification Plan form location. 2.1 (Market Rule 1, Section III.13.1.5.A) Adds FCA prior to Qualified Capacity. 2.1 (Market Rule 1, Section III.13.1.11) Adds a new Market Participant Action in Section III.13.1.11 of Market Rule 1. 2.6 (Market Rule 1, Section III.13.6.1.1.1) Replaces the app website address for the eMkt User Guide location. 2.6 (Market Rule 1, Section III.13.6.1.1.2) Replaces the app website address for the eMkt User Guide location. 2.6 (Market Rule 1, Sections III.13.6.1.1.5(a) and 1.7.1) Replaces the SOP reference with the current SOP reference. 2.6 (Market Rule 1, Section III.13.6.1.2.1) Replaces the app website address for the User Guide for External Transactions Using EES location. 2.6 (Market Rule 1, Section III.13.6.1.3.1) Replaces the app website address for the eMkt User Guide location. 2.6 (Market Rule 1, Section III.13.6.2.1.1.1) Replaces the app website address for the eMkt User Guide location. 2.6 (Market Rule 1, Section III.13.6.2.1.1.2) Replaces the app website address for the eMkt User Guide location. 2.6 (Market Rule 1, Sections III.13.6.2.1.2(a) and 1.7.11) Replaces the SOP reference with the current SOP reference. 2.6 (Market Rule 1, Sections III.13.6.2.4.2(a) and 1.7.11) Replaces the SOP reference with the current SOP reference. 2.7 (Market Rule 1, Sections III.13.7.1.1.3(a)-(h)) Replaces the app website address for the eMkt User Guide location. 2.7 (Market Rule 1, Sections III.13.7.1.2(a)-(b), (d)) Replaces the app website address for the User Guide for External Transactions Using EES location. Revision: 20 - Approval Date: September 11, 2014 Section No. Revision Summary 1. Deletes Step/Event Identifier A8 and lists the Step/Event as (Reserved). 2.1 (Market Rule 1, Section 13.1.1.2) ....Adds Resource Type IC as being applicable, revises the Participant Action and deletes the description of Participant Deliverable/Additional Information. 2.1 (Market Rule 1, Section 13.1.1.2.1) ... Deletes the phrase making only non-material changes under Participant Action. 2.1 (Market Rule 1, Section 13.1.1.2.1(a)) ... Deletes the phrase under Schedule 22 and 23 of Section II of the Tariff under Participant Action. 2.1 (Market Rule 1, Section 13.1.1.2.2.3(b)) ... Adds Resource Type IC as being applicable and adds eligible under Participant Action. 2.1 (Market Rule 1, Section 13.1.1.2.2.4) ... Adds Resource Type IC as being applicable and revises the Participant Action. 2.1 (Market Rule 1, Sections 13.1.2.3.1.1 and 13.1.2.3.1.2) ... Adds Resource Type IC as being applicable. 2.1 (Market Rule 1, Sections 13.1.2.3.2.1.2, 13.1.2.3.2.1.3, 13.1.2.3.2.1.4 and 13.1.2.3.2.1.5) ... Adds Resource Types DR and IC as being applicable and adds 13.1.3.3A and 13.1.3.3B to the Market Rule Section Number. 2.1 (Market Rule 1, Section 13.1.2.3.2.1.1.2) ... Adds Resource Type IC as being applicable and adds 13.1.3.3A and 13.1.3.3B to the Market Rule Section Number. 2.1 (Market Rule 1, Sections 13.1.3.2 and 13.1.3.3(a)(e)) ... Deletes these Sections in their entirety. 2.1 (Market Rule 1, Section 13.1.3.5.2) ... Replaces Market Participants with Project Sponsors. 2.1 (Market Rule 1, Section 13.1.4.6.2.2) ... Adds Zone at the end of the sentence. 2.1 (Market Rule 1, Section 13.1.9.1) ... Adds 5 Business Days after A28 to the Master Schedule Step/Event Identifier and revises the Participant Action description. 2.1 (Market Rule 1, Section 13.1.9.2) ... Adds As described in the Financial Assurance Policy Section VII.B.2.b to the Master Schedule Step/Event Identifier and revises the Participant Action description. 2.1 (Market Rule 1, Section 13.1.9.3) ... Revises the Participant Action. 2.1 (Market Rule 1, Section 13.1.9.3.1) ... Adds Resource Type IC as being applicable. 2.2 (Market Rule 1, Section 13.2.5.2.5.1(b)(i)) ... Replaces Network Load with Regional Network Load and deletes business under the Description of Participant Deliverables/Additional Information. 2.2 (Market Rule 1 Sections 13.2.5.2.5.1(c)(1) and (d)) ... Replaces Network Load with Regional Network Load under the Description of Participant Deliverables/Additional Information and app System and/or Process. 2.4 (Market Rule 1 Sections 13.4.2.1.3(a) and (b)) ... Replaces business days with Business Days. Attachment L ... Deletes this Section and lists the Section as (Reserved). Revision: 21 - Approval Date: December 4, 2015 Section No. Revision Summary 2.6 (Rows 10B and 10C) ... Adds new Rows 10B and 10C to the Market Participant Action Matrix regarding Rights and Obligations. Revision: 22 - Approval Date: September 11, 2015 Section No. Revision Summary 2.5 (Rows 5 through 9) ... Deletes X in the DR Resource Type column.  All Intermittent Power Resources are Generating Capacity Resources, however not all Generating Capacity Resources are Intermittent Power Resources. Therefore any reference to an Intermittent Power Resource will also include a reference to Generating Capacity Resource.  Financial Assurance must be satisfied by 8 am on the dates specified.  During the external qualification package submission window, DR milestones will be displayed in FCTS as a part of the Simple Critical Path Schedule.  This date is 35 days before the Forward Capacity Auction.  Example: If a power station consists of four generators that connect at four separate interconnection points then provide four separate forms, but in the event that the four generators connect to a single interconnection point, provide a single form.  Balancing Authority Area - For compliance with NERC reliability standards, an area comprising a collection of generation, transmission, and loads within metered boundaries for which a responsible entity (defined by NERC to be a Balancing Authority) integrates resource plans for that area ahead of time, maintains the area's load-resource balance, and supports the area's interconnection frequency in real time. This term is used interchangeably with control area. New Qualification Additional Import Information Form Page 2 of 9 July 31, 2013 2013 app.  For the purpose of completing this document, Run of River Hydro is defined by System Planning as a hydro resource that has 4 hours or less pondage when operating at full load: Hours in Full Pond - hours of generation available from a full pond without use of natural flow when generating at Max. Capacity. Hours in Full Pond represents the usable water between maximum (full) pond and minimum pond elevation requirements. Hours in Full Pond = kWh in Full Pond / Max. Capacity New Qualification Additional Import Information Form Page 4 of 9 July 31, 2013 2013 app.  Manual 20 Attachment I HYPERLINK "http://www.iso-ne.com/rules_proceds/isone_mnls/index.html"http://www.iso-ne.com/rules_proceds/isone_mnls/index.html New Qualification Additional Import Information Form Page 8 of 9 July 31, 2013 2013 app.   (continued)   app-NE PUBLIC  PAGE \* roman i app. Revision 22, Effective Date: December 31, 2015 app-NE PUBLIC Forward Capacity Market Manual Introduction app. INT- PAGE 4 Revision 22, Effective Date: December 31, 2015 app-NE PUBLIC app. INT-1 Revision 22, Effective Date: December 31, 2015 app-NE PUBLIC Forward Capacity Market Manual Section 1: Master Forward Capacity Market Schedule app. 1- PAGE 4 Revision 22, Effective Date: December 31, 2015 app-NE PUBLIC app. 1-1 Revision 22, Effective Date: December 31, 2015 app-NE PUBLIC Forward Capacity Market Manual Section 2: Market Participant Action Matrices app. 2- PAGE 83 Revision 22, Effective Date: December 31, 2015 app-NE PUBLIC app. 2- PAGE 1 Revision 22, Effective Date: December 31, 2015 app-NE PUBLIC Forward Capacity Market Manual Section 3: Requirements Applicable to Dispatchable Asset Related Demands app. 3- PAGE 3 Revision 22, Effective Date: December 31, 2015 app-NE PUBLIC app. 3- PAGE 1 Revision 22, Effective Date: December 31, 2015 app-NE PUBLIC Forward Capacity Market Manual Attachment I: Northeast MOU General ICAP Principles app. I- PAGE 3 Revision 25, Effective Date: June 1, 2010 app. A- PAGE 1 Revision 22, Effective Date: December 31, 2015 app-NE PUBLIC Forward Capacity Market Manual Attachment C: Host Participant Assigned Meter Reader Requirements app. C- PAGE 2 Revision 22, Effective Date: December 31, 2015 app-NE PUBLIC app. C- PAGE 1 Revision 22, Effective Date: December 31, 2015 app-NE PUBLIC Forward Capacity Market Manual Attachment G: Data Requirement Matrix for Demand Resources app. G- PAGE 4 Revision 25, Effective Date: June 1, 2010 app. D- PAGE 1 Revision 22, Effective Date: December 31, 2015 app-NE PUBLIC Forward Capacity Market Manual Attachment I: Northeast MOU General ICAP Principles app. I- PAGE 3 Revision 22, Effective Date: December 31, 2015 app-NE PUBLIC app. I- PAGE 1 Revision 22, Effective Date: December 31, 2015 app-NE PUBLIC Forward Capacity Market Manual Attachment I: Northeast MOU General ICAP Principles app. I- PAGE 2 Revision 25, Effective Date: June 1, 2010 app. J- PAGE 1 Revision 22, Effective Date: December 31, 2015 app-NE PUBLIC Forward Capacity Market Manual Attachment K: Maintenance Allotment Hours app. K- PAGE 3 Revision 22, Effective Date: December 31, 2015 app-NE PUBLIC app. K- PAGE 1 Revision 22, Effective Date: December 31, 2015 app-NE PUBLIC Forward Capacity Market Manual Attachment L: Temporary Provisions for Qualification and Related Items for Full Integration of Demand Resources app. L- PAGE 16 Revision 20, Effective Date: September 11, 2015 Forward Capacity Market Manual Attachment L: Temporary Provisions for Qualification and Related Items for Full Integration of Demand Resources app. L- PAGE 1 Revision 22, Effective Date: December 31, 2015 app-NE PUBLIC Forward Capacity Market Manual Attachment M: New Import Capacity Resource Qualification Information Form app. M- PAGE 9 Revision 22, Effective Date: December 31, 2015 app-NE PUBLIC app. M- PAGE 1 Revision 22, Effective Date: December 31, 2015 app-NE PUBLIC Forward Capacity Market Manual Revision History app. REV- PAGE 2 Revision 22, Effective Date: December 31, 2015 app-NE PUBLIC app. REV- PAGE 1 Revision 22, Effective Date: December 31, 2015 app-NE PUBLIC #$;ABQR\]^otwxz~      % 7 8 = D N Z } ~      hu hX6] h6] hP;6] hDx6]hDxhNmhQ hx6] h_6]h$@hxyh ZhcGhH3hG=h.ZhhDhxh1h_:$COPQR_  O ~ xwQPgdQgd$a$P`~  $ E q ! z  , n   b s xgdwgdgd'wgd'0H^HgdJT0gdHxgdHwxgdDx ! 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