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Search Results For 'State and Local Procedural Requirements' ( 225 matches )

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DRAFT Order 1000 Att FF_Generic

In addition to the requirements of this Attachment FF, there may be state or local procedural requirements applicable to the planning or siting of transmission facilities by the Transmission Owners. A current list of those requirements can be found on the Transmission Provider's website.
federal laws, state laws, local laws, state and local building codes, federal regulatory requirements, state and local regulatory requirements, state and local licensing authorities, the National Electric Safety Code, the National Electric Code, Applicable Reliability Standards, and Good Utility Practice;
local planning reliability or economic planning criteria of the Transmission Owner, or required by State or local authorities, and any economic or other planning criteria or metrics defined in this Attachment FF. Transmission Owners are required to annually provide updated copies of local planning criteria for posting on the Transmission Provider'
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20130626 PAC Item 03 Draft Attachment FF Changes

In addition to the requirements of this Attachment FF, there may be state or local procedural requirements applicable to the planning or siting of transmission facilities by the Transmission Owners. A current list of those requirements can be found on the Transmission Provider's website.
and maintenance of transmission facilities including, but not limited to, federal, state and local laws, state and local building codes, federal, state and local regulatory requirements, state and local licensing authorities, the National Electric Safety Code, the National Electric Code, Applicable Reliability Standards, and Good Utility Practice;
including accepted NERC reliability standards and reliability standards adopted by Regional Entities, local planning reliability or economic planning criteria of the Transmission Owner, or required by State or local authorities, any economic or other planning criteria or metrics defined in this Attachment FF, and any Applicable Laws and Regulations.
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MOD-033-1 Model Validation Process

with Transmission Planners using reference item 10 to develop a requirement for provision of dynamic load data by Transmission Owners or to use local procedures and Tariff references to obtain dynamic load data. R3. Upon receipt of written notification from its Planning Coordinator or Transmission Planner regarding technical concerns with the data submitted under Requirement R2,
contingency event conditions and prepare a steady state model by following procedure laid out in Section 1.3. Thereafter perform dynamic model validation. The dynamic model validation process is show in Figure 2-1 below. Figure 21 R1.2 Dynamic model validation process Selection of Local Dynamic Event The following dynamic events shall be considered.
Steady State Validation , Dynamic Model Validation PSSE .raw or .sav format Table 51 list of data required from RC and TOP End of procedure. Reference materials provided in Appendices. Case Preparation and Sanity Checks Guidelines The items in Table A1 should be considered for case preparation of the model during the application of the R1.
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20170517 EPPSRWG Item XX 2016 EP PSR Drill Report Final Draft

Day 1 ended with an opportunity for a local debriefing session at the MISO and participant sites. Day 2 began with a review the MISO Interconnection Checklist and interconnection requirements and ended with a one hour local debrief and discussion at MISO and participant sites. During the first day of the drills the initial system conditions (complete blackout)
opportunity to tie small internal islands using their local procedures, as well as take advantage of situations where neighboring facilities of other companies were able to provide external sources of cranking power. Updates of transmission facility status were submitted to the MISO using the Restoration Tracking Forms and were compiled into overview maps accessed via the MISO Extranet.
The drill is effective practice at utilizing blackstart operating procedures Winter scenario helped operators consider challenges that would not normally be faced during a restoration Operators were engaged in training activities Two-day format provided adequate time for activities and review of procedures Issues/Suggestions: Restoration tracking form needs work-missing facilities,
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20170215 EPPSRWG Item 02 2016 EP PSR Drill Report Draft

Day 1 ended with an opportunity for a local debrief session at the MISO and participant sites. Day 2 began with a review the MISO Interconnection Checklist and interconnection requirements and ended with a one hour local debrief and discussion at MISO and participant sites. During the first day of the drills the initial system conditions (complete blackout)
opportunity to tie small internal islands using their local procedures, as well as take advantage of situations where neighboring facilities of other companies were able to provide external sources of cranking power. Updates of transmission facility status were submitted to the MISO using the Restoration Tracking Forms and were compiled into overview maps accessed via the MISO Extranet.
The drill is effective practice at utilizing blackstart operating procedures Winter scenario helped operators consider challenges that would not normally be faced during a restoration Operators were engaged in training activities Two-day format provided adequate time for activities and review of procedures Issues/Suggestions: Restoration tracking form needs work-missing facilities,
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20150318 EPPSRWG Item 07 PSR Drill Final Report Clean (1)

local procedures, as well as take advantage of situations where neighboring facilities of other companies were able to provide external sources of cranking power. Updates of transmission facility status were submitted to the MISO using the ESID and the Restoration Tracking Forms were compiled into overview maps within ESID where available or accessed via the MISO Extranet for participants
opportunity for a local debrief session at the MISO and participant sites. Day 2 began with a review of NERC Reliability Standard EOP-006-2 and ended with a one hour local debrief and discussion at MISO and participant sites. During the first day of the drills the initial system conditions (complete blackout) were presented to the operators and the initial restoration steps began.
requirements for the RC to invite TOPs and GOPs to the drills were imposed. These Standards also include requirements for those TOPs and GOPs to participate when requested. Therefore, as part of the 2014 drills all TOPs listed in the MISO PSR plan, as well as all GOPs with blackstart resources and other resources that are listed in those TOP plans and that are necessary to achieve
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20150318 EPPSRWG Item 07 PSR Drill Final Report Redline

local procedures, as well as take advantage of situations where neighboring facilities of other companies were able to provide external sources of cranking power. Updates of transmission facility status were submitted to the MISO using the ESID and the Restoration Tracking Forms were compiled into overview maps within ESID where available or accessed via the MISO Extranet for participants
opportunity for a local debrief session at the MISO and participant sites. Day 2 began with a review of NERC Reliability Standard EOP-006-2 and ended with a one hour local debrief and discussion at MISO and participant sites. During the first day of the drills the initial system conditions (complete blackout) were presented to the operators and the initial restoration steps began.
requirements for the RC to invite TOPs and GOPs to the drills were imposed. These Standards also include requirements for those TOPs and GOPs to participate when requested. Therefore, as part of the 2014 drills all TOPs listed in the MISO PSR plan, as well as all GOPs with blackstart resources and other resources that are listed in those TOP plans and that are necessary to achieve
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Queue Process FAQs

Transmission Access is one part of the overall project work, and the reformed interconnection procedure requires milestones indicating that progress is being made in other areas of the development plan, too. We currently have projects in the MISO queue. Can we amend our projects in the MISO queue to connect to GPE or any other FLIP at a later date?
company letterhead signed by an officer of the company will be required. The letter should state that the existing site is sufficient to accommodate the new unit(s) and additional land is not required for the project. Such letter should be accompanied by a map of the site showing the location of the existing units and the proposed location of the new unit(s) to be added to the site.
Midwest ISO also requires a document signed by a company executive that states that all of the listed agreements are on file in their entirety, all referenced land is within the proposed project boundaries and those agreements constitute 50% (or more) ownership of the project's total site.
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MOD-032 Model Data Requirements and Reporting Procedures

requirement R1.3 the Requirements and Reporting Procedures manual is posted on the MISO web site at the following location: https://www.misoenergy.org/PLANNING/MODELS/Pages/MOD-032.aspx The purpose of this document is to outline these data reporting procedures needed to support the development of power flow and dynamics simulation base case models that realistically simulate steady
Pursuant to requirement R1 of MOD-032-1, MISO as a NERC Planning Coordinator (PC), and its NERC Transmission Planners (TPs) have jointly developed modeling data requirements and reporting procedures for MISO's planning area. Transmission Planners that have participated in the development of this document are as follows.
state model outlined in Section 3. If changes are required to the power flow data for dynamics they should be reflected in the steady-state power flow cases and the appropriate changes entered in MOD. Dynamics Representation Generators At a minimum, all generators with a nameplate greater than 20 MVA or a facility with an aggregated nameplate greater than 75 MVA must be modeled
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20130411 ENGCTF Item 10a Supplemental Issues Related to Resource Adequacy_Draft

s Emergency Operating Procedures require that firm load be shed, on a pro rata basis, over the entire energy deficient area. Thus, if accredited as a planning resource, gas fired generator outages may impact stakeholders other than the generator owner. While gas-fired generation availability has not historically negativity impacted reliability,
a desired end state when appropriate, current known challenges to reaching the desired end state, and when appropriate, identified ways and means to achieve the desired end state. This paper is not intended to advocate for any individual stakeholder's point of view nor the point of view of any group of stakeholders,
Should Capacity Resource accreditation include fuel requirements If so, what are the requirements? Are Capacity Resources paid sufficiently to adequately acquire fuel How does intraday gas market illiquidity, issues with gas nomination, and gas scheduling impact generation reliability both on an individual and footprint wide basis?
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20171009 MHTT Draft Merchant HVDC Transmission Connection Procedures

Information solely to fulfill its obligations to another Party under these procedures or its regulatory requirements. 9.1.6Order of Disclosure If a court or a Government Authority or entity with the right, power, and apparent authority to do so requests or requires any Party, by subpoena, oral deposition, interrogatories, requests for production of documents, administrative order,
of any local furnishing bond(s) used to finance Transmission Owner's facilities that would be used in providing such Interconnection Service. 9.6.2Alternative Procedures for Requesting MHVDC Transmission Connection Service. If Transmission Owner determines that the provision of MHVDC Transmission Connection Service requested by MHVDC Connection Customer could jeopardize the tax-
s established Generator Interconnection Procedures, as described in Attachment X of the Tariff, and shall be subject to all of the requirements set forth in Attachment X. Requests for Injection Rights for energy, similar to evaluation of ERIS, will include short circuit/fault duty, steady state (thermal and voltage) and stability analyses.
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20140625-26 EPPSRWG Item 03 RTO-EOP-004-r14.1 Transmission Emergency Procedure

revised MISO procedure names in reference section to be current and revised term used for MISO restricted access procedures. Procedure Owner Approval on file. Kevin Sherd APR 13, 2012 JUN 01, 2012 RTO-EOP-004-r10 Remove Local Transmission Emergencies (moving to RA-OP-001).
where it is reasonable for the RC to expect that conditions will worsen and require declaration of a Transmission System Emergency. Actions During a Transmission System Emergency Prior to declaring a Transmission System Emergency, the RC will Verify that real-time values are accurate. Verify that State Estimator and Real Time Contingency Analysis (RTCA) solutions are reasonable.
Emergency Procedure RTO-EOP-002-A Non-Market Footprint and Sub-Area Capacity Emergencies Procedure RTO-OP-006 Manual and Emergency Redispatch Procedure RTO-RA-OP-003 RTO-I-OPC-018 Procedure Description Criteria for Transmission System Emergencies A Transmission System Emergency condition exists when one or more of the following criteria are met for transmission lines 100 kV and higher,
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20140625-26 EPPSRWG Item 03 RTO-EOP-003-r14 MISO Supply Surplus Procedure

This procedure outlines the set of plans to mitigate operating emergencies on the Transmission System due to supply surplus conditions. Based on the scheduled interchange, on-line Resources, and transmission security requirements, the MISO Balancing Authority Area (MBAA) or a sub-area may experience situations during light load periods when on-
expected duration of the conditions requiring the initiation/termination of the Minimum Generation Emergency Alert/Warning/Event MISO Management calls (during Minimum Generation Events). E-mail Distribution Groups: "MISO Alerts BA and TO" "MISO Alerts FERC, State Comm., Regional Reliability Organization (RRO), Neighboring RCs & BAs" "RT Ops Notification" Refer to RTO-
Imported document into most recent Procedure template; changed references to "Midwest ISO" to "MISO". Procedure Owner approval on file. Mike McMullen APR 13, 2012 JUN 01, 2012 RTO-EOP-003-r11 Revised to reflect MCS replacing OICL. Updated website location. Annual review; Procedure owner approval on file.
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20160302 RASC Item 04g Module E-1

Peak Demand times the applicable zonal Auction Clearing Price less any zonal deliverability benefits plus any Local Clearing Requirement Charges for the Local Resource Zone where the wholesale load is located. e. An LSE may challenge the EDC Demand forecast under the dispute resolution procedures pursuant to Section 12 or it may refer the dispute to the Commission for resolution.
Local Resource Zone Peak Demand requirements on the Transmission System. These requirements recognize and are complementary to the reliability mechanisms of the states and the Regional Entities (RE) within the Transmission Provider Region. Nothing in this Module E-1 affects existing state jurisdiction over the construction of additional capacity or the authority of states to set
any zonal deliverability benefits plus any Local Clearing Requirement Charges for the Local Resource Zone where the load is located. c. In a state that permits retail load switching and where the EDC has adopted the daily peak load default method in Section 69A.1.2.1, the Transmission Provider shall allocate resource capacity costs on a daily basis to LSEs by multiplying the LSE'
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20160302 RASC Item 04g Incremental Changes Module E-1 Jan 2016 to Feb 2016

Peak Demand times the applicable zonal Auction Clearing Price less any zonal deliverability benefits plus any Local Clearing Requirement Charges for the Local Resource Zone where the wholesale load is located. e. An LSE may challenge the EDC Demand forecast under the dispute resolution procedures pursuant to Section 12 or it may refer the dispute to the Commission for resolution.
Local Resource Zone Peak Demand requirements on the Transmission System. These requirements recognize and are complementary to the reliability mechanisms of the states and the Regional Entities (RE) within the Transmission Provider Region. Nothing in this Module E-1 affects existing state jurisdiction over the construction of additional capacity or the authority of states to set
any zonal deliverability benefits plus any Local Clearing Requirement Charges for the Local Resource Zone where the load is located. c. In a state that permits retail load switching and where the EDC has adopted the daily peak load default method in Section 69A.1.2.1, the Transmission Provider shall allocate resource capacity costs on a daily basis to LSEs by multiplying the LSE'
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20170712 RASC Item 03b Locational Module E-1

Peak Demand times the applicable zonal Auction Clearing Price less any zonal deliverability benefits plus any Local Clearing Requirement Charges for the Local Resource Zone where the wholesale load is located. e. An LSE may challenge the EDC Demand forecast under the dispute resolution procedures pursuant to Section 12 or it may refer the dispute to the Commission for resolution.
Local Resource Zone Peak Demand requirements on the Transmission System. These requirements recognize and are complementary to the reliability mechanisms of the states and the Regional Entities (RE) within the Transmission Provider Region. Nothing in this Module E-1 affects existing state jurisdiction over the construction of additional capacity or the authority of states to set
any zonal deliverability benefits plus any Local Clearing Requirement Charges for the Local Resource Zone where the load is located. c. In a state that permits retail load switching and where the EDC has adopted the daily peak load default method in Section 69A.1.2.1, the Transmission Provider shall allocate resource capacity costs on a daily basis to LSEs by multiplying the LSE'
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20170809 RASC Item 02a Locational Module E-1

Peak Demand times the applicable zonal Auction Clearing Price less any zonal deliverability benefits plus any Local Clearing Requirement Charges for the Local Resource Zone where the wholesale load is located. e. An LSE may challenge the EDC Demand forecast under the dispute resolution procedures pursuant to Section 12 or it may refer the dispute to the Commission for resolution.
Local Resource Zone Peak Demand requirements on the Transmission System. These requirements recognize and are complementary to the reliability mechanisms of the states and the Regional Entities (RE) within the Transmission Provider Region. Nothing in this Module E-1 affects existing state jurisdiction over the construction of additional capacity or the authority of states to set
any zonal deliverability benefits plus any Local Clearing Requirement Charges for the Local Resource Zone where the load is located. c. In a state that permits retail load switching and where the EDC has adopted the daily peak load default method in Section 69A.1.2.1, the Transmission Provider shall allocate resource capacity costs on a daily basis to LSEs by multiplying the LSE'
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20130808 SAWG Item 05 Module E-1 Draft Changes

Local Resource Zone Peak Demand requirements on the Transmission System. These requirements recognize and are complementary to the reliability mechanisms of the states and the Regional Entities (RE) within the Transmission Provider Region. Nothing in this Module E-1 affects existing state jurisdiction over the construction of additional capacity or the authority of states to set
right physical locations within the Transmission Provider Region to reliably meet Demand and LOLE requirements. The geographic boundaries of each of the LRZs will be based upon analysis that considers: (1) the electrical boundaries of Local Balancing Authorities; (2) state boundaries; (3) the relative strength of transmission interconnections between Local Balancing Authorities;
5 Establishment of Local Reliability Requirement Version: 0.0.0 Effective: 10/1/2012 Establishment of Local Reliability Requirement By November 1st prior to a Planning Year, the Transmission Provider will establish a Local Reliability Requirement (LRR) metric for each LRZ to determine the quantity of Unforced Capacity needed such that the LRZ would achieve an LOLE of 0.
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20130313 EPPSRWG Item 07a RTO-PSR-001 MISO Power System Resotration Plan Manual Volume I Version 4.2 jer20130306_EOP0062

Local Balancing Authorities and Reliability Coordinators should include staffing plans in procedures for addressing BES emergency response. After an event occurs, the affected entities should assess their staffing requirements to ensure a safe, orderly and timely system restoration, and will ensure the requisite resources are made available to realize these objectives.
Agreements are in place between MISO and these other RCs to clearly state the requirements of both parties including requirement for system restoration coordination. The relationship and communications between the MISO RC and the TOPs, BAs and GOPs is central to the development and successful implementation of the restoration plan.
MISO Restoration Plans and Procedures NERC Power System Restoration Requirements NERC Standard EOP-005 establishes the requirements for TOP System Restoration Plans. NERC Standard EOP-006 defines the requirements for the MISO RC System Restoration Plan. MISO System Restoration Process: 1.
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RTO-PSR-001 Power System Restoration Manual Volume I Version 3.0_DRAFT

Local Balancing Authorities and Reliability Coordinators should include staffing plans in procedures for addressing BES emergency response. After an event occurs, the affected entities should assess their staffing requirements to ensure a safe, orderly and timely system restoration, and will ensure the requisite resources are made available to realize these objectives.
Agreements are in place between MISO and these other RCs to clearly state the requirements of both parties including requirement for system restoration coordination. The relationship and communications between the MISO RC and the TOPs, BAs and GOPs is central to the development and successful implementation of the restoration plan.
MISO Restoration Plans and Procedures NERC Power System Restoration Requirements NERC Standard EOP-005 establishes the requirements for TOP System Restoration Plans. NERC Standard EOP-006 defines the requirements for the MISO RC System Restoration Plan. MISO System Restoration Process: 1.
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RTO-PSR-001 MISO Power System Restoration Plan Manual Volume I Version 4.2_DRAFT

Local Balancing Authorities and Reliability Coordinators should include staffing plans in procedures for addressing BES emergency response. After an event occurs, the affected entities should assess their staffing requirements to ensure a safe, orderly and timely system restoration, and will ensure the requisite resources are made available to realize these objectives.
Agreements are in place between MISO and these other RCs to clearly state the requirements of both parties including requirement for system restoration coordination. The relationship and communications between the MISO RC and the TOPs, BAs and GOPs is central to the development and successful implementation of the restoration plan.
MISO Restoration Plans and Procedures NERC Power System Restoration Requirements NERC Standard EOP-005 establishes the requirements for TOP System Restoration Plans. NERC Standard EOP-006 defines the requirements for the MISO RC System Restoration Plan. MISO System Restoration Process: 1.
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20130313 EPPSRWG Item 07a RTO-PSR-001 MISO Power System Restoration Plan Manual Volume 1 Version 4.2 DRAFT

Local Balancing Authorities and Reliability Coordinators should include staffing plans in procedures for addressing BES emergency response. After an event occurs, the affected entities should assess their staffing requirements to ensure a safe, orderly and timely system restoration, and will ensure the requisite resources are made available to realize these objectives.
Agreements are in place between MISO and these other RCs to clearly state the requirements of both parties including requirement for system restoration coordination. The relationship and communications between the MISO RC and the TOPs, BAs and GOPs is central to the development and successful implementation of the restoration plan.
MISO Restoration Plans and Procedures NERC Power System Restoration Requirements NERC Standard EOP-005 establishes the requirements for TOP System Restoration Plans. NERC Standard EOP-006 defines the requirements for the MISO RC System Restoration Plan. MISO System Restoration Process: 1.
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20150318 EPPSRWG Item 08 RTO-PSR-001 MISO PSR Plan Manual Vol I Ver 8

Local Balancing Authorities and Reliability Coordinators should include staffing plans in procedures for addressing BES emergency response. After an event occurs, the affected entities should assess their staffing requirements to ensure a safe, orderly and timely system restoration, and will ensure the requisite resources are made available to realize these objectives.
Notify local, state, federal or regulatory agencies and submit final reports to DOE, NERC, Regional Entities and others as appropriate or required. MISO's Responsibilities and Authority MISO as the RC has responsibility and authority over the transmission facilities belonging to the TOPs that are in its reliability footprint.
Notify local, state, federal or regulatory agencies and submit final reports to DOE, NERC, Regional Entities and others as appropriate or required. Balancing Authority Role and Responsibility The BA within the MISO RC footprint is responsible to integrate resource plans ahead of time, maintain load-interchange-generation balance within a BA Area,
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RTO-PSR-001 MISO Power System Restoration Plan Manual Volume I Version 4.2_DRAFT

Local Balancing Authorities and Reliability Coordinators should include staffing plans in procedures for addressing BES emergency response. After an event occurs, the affected entities should assess their staffing requirements to ensure a safe, orderly and timely system restoration, and will ensure the requisite resources are made available to realize these objectives.
Agreements are in place between MISO and these other RCs to clearly state the requirements of both parties including requirement for system restoration coordination. The relationship and communications between the MISO RC and the TOPs, BAs and GOPs is central to the development and successful implementation of the restoration plan.
MISO Restoration Plans and Procedures NERC Power System Restoration Requirements NERC Standard EOP-005-2 R1 establishes the requirements for TOP System Restoration Plans. NERC Standard EOP-006-2 R1 defines the requirements for the MISO RC System Restoration Plan. MISO System Restoration Process: 1.
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20140211 MSWG Item 02b BPM-012-r11 Transmission Settlements_REDLINE

the tax collections and the state/locality to which they are due. Data Requirements The information needed to calculate Schedule 12 charges will be kept in a collection of tables. They will include: Transmission Owners expecting MISO to collect GRT Customers exempt and the locality of the exemption State/locality and the percentage of the PORs and PODs residing within that area
billing, and accounting requirements. Procedures MISO Transmission Settlements develops, implements, and maintains Procedures for administering Transmission Settlements business processes. MISO Settlement Services MISO provides a wide variety of services to its members, Transmission Customers, and others.
reactive power revenue requirements or stated rates for a Transmission Pricing Zone. Rates are recalculated when a Qualified Generator status: Becomes effective on the first day of the month immediately following acceptance of the revenue requirement by FERC; Becomes effective on the first day of the month if FERC acceptance of such revenue requirement is on the first day of the month;
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