Checklist for Incoming Transmission Owners (TOs)

1. Membership Application. The incoming Transmission Owner is required to submit a fully executed Transmission-Owning Membership Application, which will be acted on by the MISO Board of Directors at a regularly scheduled Board meeting. Please forward an executed copy of the Membership Application to membership@misoenergy.org and TOIntegrations@misoenergy.org. The Membership Application can be accessed from MISO’s website at the following link: Membership Information [scroll down and click on “Member Application-Transmission Owners”].

2. Signature Page to Transmission Owners Agreement. The incoming Transmission Owner is required to submit a fully executed signature page to the “Agreement of Transmission Facilities Owners to Organize the Midcontinent Independent System Operator, Inc., A Delaware Non-Stock Corporation” (“Transmission Owners Agreement”). This signature page can be accessed from MISO’s website at the above-referenced link. (Please forward an executed copy to membership@misoenergy.org and TOIntegrations@misoenergy.org.) Such signature page to the Transmission Owners Agreement will be reported to the Federal Energy Regulatory Commission (“FERC”) in MISO’s Electric Quarterly Report (“EQR”).

1. Transmission Facilities Review. To determine which facilities will be subject to FERC’s open access requirements and which facilities will remain under the state's jurisdiction for purposes of retail stranded cost adders or other retail regulatory purposes, FERC developed a seven-factor test in Order No. 888⁴ that determines which facilities are Local Distribution Facilities.

If applicable, the incoming Transmission Owner may be required to forward to TOIntegrations@misoenergy.org a copy of any order (from FERC or a state regulatory commission) concerning any determination of the classification of its facilities based on a seven-factor test. If the incoming Transmission Owner is not subject to regulation by a regulatory authority, it shall apply to MISO for a determination of the classification of its facilities pursuant to Article II.C.2 of Appendix C of the Transmission Owners Agreement, and MISO will conduct a test in order to determine which facilities are Transmission Facilities appropriate for inclusion in Appendix H of the common template referenced above, and which facilities are Non Transferred Transmission Facilities appropriate for inclusion in Appendix G of the common template referenced above. If the incoming Transmission Owner has any concerns on classification of its facilities as Transmission, the transmission review test should be completed before signing the Transmission Owners Agreement. The following information is required for any such transmission review:

1. 1. Preliminary Functional Control and Non-Transferred Facility listing referenced above.
   2. One-line diagrams (also called switching diagrams or operating diagrams) of the Transmission Facilities referenced above.
   3. Geographic transmission map(s) of Transmission Owner’s system.

Please see Transmission Determination Business Practice Manual 028 at the following link: Business Practice Manuals [scroll down and click on “BPM 028 – Transmission Determination Process”].

⁴ See, Promoting Wholesale Competition Through Open Access Non-Discriminatory Transmission Services by Public Utilities; Recovery of Stranded Costs by Public Utilities and Transmitting Utilities, Order No. 888, 61 Fed. Reg. 21,540 (1996), FERC Stats. & Regs. 31,036 (1996), order on reh'g, Order No. 888-A, 62 Fed. Reg. 12,274 (1997), FERC Stats. & Regs. 31,048 (1997), order on reh'g, Order No. 888-B, 81 FERC 61,248 (1997), order on reh'g, Order No. 888-C, 82 FERC 61,046 (1998), aff'd in part sub nom. Transmission Access Policy Study Group v. FERC, 225 F.3d 667 (D.C. Cir. 2000), aff'd sub nom. New York v. FERC, 535 U.S. 1 (2002).

2. Listing of the incoming Transmission-Owning Member’s (i) Transmission Facilities Transferred to MISO’s Functional Control Pursuant to Appendix H (Transmission System Facilities) and (ii) Non-transferred Transmission Facilities that are subject to Appendix G (Agency Agreement) of the Transmission Owners Agreement. The criteria for facilities transferred under MISO’s functional control is defined in the Transmission Owners Agreement, as follows:

1. Review of Compliance Matters

a. Review whether a NERC registration, certification, or certification review is needed for the incoming Transmission Owner or for MISO. Pursuant to NERC Rules of Procedure (“ROP”), Appendix 5A of the Organization Registration and Certification Manual, entities including Reliability Coordinator (“RC”), Transmission Operator (“TOP”), Balancing Authority (“BA”), Planning Authority (“PA”), Transmission Planner (“TP”), Transmission Service Provider (“TSP”), and Transmission Owner (“TO”) are required to be registered and certified for their functions. Certification reviews may be required for the registered entity’s footprint or other changes.

b. Review whether NERC Coordinated Functional Registrations (“CFRs”) need to be updated as a result of the incoming Transmission Owner. A CFR is an arrangement between multiple entities to clearly identify compliance responsibilities. The incoming Transmission Owner may qualify to join existing NERC CFRs, which have the effect of reducing NERC audit scope for certain compliance functions that MISO performs on behalf of its members.

c. Obtain Regional Entity and NERC committee approvals of updated MISO Reliability Plan, if applicable. MISO will update and obtain approval of its Reliability Plan for its footprint, member, or functional changes as necessary. Such Reliability Plan is used to communicate and coordinate any changes with neighboring seams.

1. Training. MISO’s website offers many training materials at Levels 100, 200 and 300 to introduce new market participants and members to MISO and provide focused knowledge on specific aspects of MISO’s operations. To access training materials, visit the Customer Training page on MISO’s website and create an account on MISO’s Learning Center.

In addition to training, MISO’s website also offers many Business Practice Manuals (BPMs), user guides, and policy documents. See below for a list of highlighted documents suggested for incoming Transmission Owners’ review.
 

• Transmission Owners Agreement
• MISO Energy and Operating Reserves Tariff
• Self-Service Local Security Administrator (SSLSA) User Guide
• Local Security Administrator (LSA) Policy
• BPM 002 – Energy and Operating Reserve Markets
• BPM 012 – Transmission Settlements
• BPM 015 – Generation Interconnection
• BPM 019 – Monthly Transmission Billing
• BPM 020 – Transmission Planning
• BPM 021 – Transmission Pricing
• BPM 023 – Alternative Dispute Resolution

1. MISO eTariff Filing Guidelines for MISO Transmission Owners. Please refer to the MISO’s eTariff Filing Guidelines, which are available at the following link: Filing Guidelines. Such guidelines document MISO’s procedures and timeline requirements when it is necessary to coordinate with MISO’s Legal Department regarding the submittal of Section 205 filings with FERC. Adherence to these guidelines ensures adequate time and resources are available to the Transmission Owner when it is necessary for MISO’s Legal Department to submit, as Administrator of the MISO Tariff, any FERC filings on behalf of the Transmission Owner via MISO’s eTariff software.

2. Pricing Zones. A determination will be made as to whether the incoming Transmission Owner will be part of an existing pricing Zone or a new pricing Zone. If the incoming Transmission Owner will be a separate pricing Zone or is joining an existing joint pricing Zone, MISO will coordinate with the incoming Transmission Owner to submit a Section 205 filing with FERC, amending Schedules 7, 8, 9 and 26 of MISO’s Tariff to incorporate the new pricing Zone or amending the existing pricing, Zone. Pursuant to the Transmission Owners Agreement,⁵ pricing Zones may only be changed to:

(i) reflect the effectuation of a merger (or consolidating and reorganization),
(ii) add a new Transmission Owner that operates a balancing authority area in existence on or before the “date of the initial filing with FERC to establish MISO,”⁶ or
(iii) reflect the withdrawal from MISO of an Owner or Owners.

⁵ See, Appendix C of the Transmission Owners Agreement.
⁶ The date of the initial FERC filing seeking authorization for the establishment of MISO was filed on January 15, 1998 in Docket No. ER98-1438-000. See, Order Conditionally Authorizing Establishment of Midwest Independent Transmission System Operator and Establishing Hearing Procedures, Midwest Indep. Transmission Sys. Operator, Inc., 84 FERC § 61,231 (1998).

3. Local Resource Zones (Attachment VV of MISO’s Tariff). Attachment VV depicts a map of the Local Resource Zone boundaries contained within the MISO Region. MISO will, as necessary, develop new Local Resource Zones (LRZs) to reflect the need for an adequate amount of Planning Resources to be located in the right physical locations within its Region to reliably meet Demand and resource adequacy 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; (4) the results of LOLE studies; (5) the relative size of LRZs; and (6) natural geographic boundaries such as lakes and rivers.

4.Cost Allocation Zones (Attachment WW of MISO’s Tariff). The Zones identified in Attachment WW are used for allocating the costs of Market Efficiency Projects. Within the map, each Cost Allocation Zone is comprised of one or more Transmission Pricing Zones, and the map represents the approximate boundary of each of the Zones. One hundred percent of the costs of the Market Efficiency Projects are allocated to all Transmission Customers in each of the Cost Allocation Zones, as defined in Attachment WW. The cost allocated to each Cost Allocation Zone is based on the expected benefit based on the benefit metrics described in Attachment FF-71.

5. Rate Structure Matters. If the incoming Transmission Owner intends to vary from the standard Attachment O (Rate Formulae), Attachment MM (MVP Charge), and Attachment GG (Network Upgrade Charge) template(s) for transmission services under MISO’s Tariff, the incoming Transmission Owner shall coordinate with MISO, as Administrator of its Tariff, to file with FERC either new templates or revisions to Attachment O (Rate Formulae), Attachment MM (MVP Charge), and Attachment GG (Network Upgrade Charge) so as to amend such templates. A Transmission Owner’s Attachment O should include its Transmission Facilities transferred to MISO’s functional control, including Appendix G (Agency Agreement) facilities. However, Attachment O rates should not include any facilities considered to be Local Distribution Facilities or generation step-up facilities.

For assistance in populating the templates or the applicable revisions to the rate structure, including Attachment O of MISO’s Tariff, please contact MISO’s Transmission Rates Business Partner. See also, Item 11 above, which provides information relative to the Legal Department’s eTariff Filing Guidelines and timing requirements for coordinating Section 205 filings with FERC.

As transmission billing and revenue distribution are key items that are often intertwined with rate structure issues, incoming Transmission Owners should review Appendix C of the Transmission Owners Agreement.

6. MISO will also create a link on its website to the incoming Transmission Owner’s Rate Data. A new link on MISO’s website shall be created by MISO for each entity subject to MISO’s Attachment O Formula Rate Protocols. Each entity submitting an Attachment O for rate recovery shall have public posting and notification requirements per the applicable Formula Rate Protocols.

7. MISO Transmission Expansion Plan. 

a. Attachment FF-3 of MISO’s Tariff (Transmission Owners Associated with Each Planning Sub-Region). The incoming Transmission Owner will coordinate with MISO’s Director or Manager of Expansion Planning to discuss within which Planning-SubRegion the new Transmission Owner should be included. This determination should be jointly communicated by Membership Services and Expansion Planning personnel to MISO’s Legal Department and MISO will submit a Section 205 filing with FERC to revise Attachment FF-3 of its Tariff to include reference to the new Transmission Owner in Attachment FF-3.

b. Attachment FF-4 of MISO’s Tariff (Transmission Owners Integrating Local Planning Processes into MISO’s Planning Processes per Order No. 890). The incoming Transmission Owner will coordinate with MISO’s Director or Manager of Expansion Planning to inform MISO planners if it intends to integrate its local planning processes into MISO’s planning process by way of Attachment FF-4 of MISO’s Tariff. If the incoming Transmission Owner intends to integrate its local planning processes by means of Attachment FF- 4, such information will be jointly communicated by Membership Services and Expansion Planning personnel to MISO’s Legal Department and MISO will submit a Section 205 filing with FERC to revise Attachment FF-4 of its Tariff to include reference to the new Transmission Owner in Attachment FF-4.

c. Attachment FF-5 of MISO’s Tariff (Transmission Owners Retaining Separate Local Planning Processes per Order No. 890). If, however, the incoming Transmission Owner intends to retain the local planning provisions of its own tariff, such information will be jointly communicated by Membership Services and Expansion Planning personnel to MISO’s Legal Department. Thereafter, MISO (as the Administrator of its Tariff) will coordinate with the incoming Transmission Owner in the submittal of a Section 205 filing with FERC to revise Attachment FF-5 of MISO’s Tariff to include reference to the new Transmission Owner in Attachment FF-5, as well as the new Transmission Owner’s local planning provisions in Attachment FF of MISO’s Tariff.

8. Notices of Succession. If applicable, the incoming Transmission Owner shall coordinate with MISO, as the Administrator of MISO’s Tariff, in the submittal of a Section 205 filing with FERC so as to assign Transmission Service Agreements from the Transmission Owner’s tariff to MISO’s Tariff as the provision of transmission and interconnection services may no longer be provided under the incoming Transmission Owner’s tariff upon its effective integration into MISO. Such filing will contractually provide for any transactions that will continue flowing on the effective date of the incoming Transmission Owner’s transfer of functional control to MISO.

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1. Grandfathered Agreements (“GFAs”). If applicable, MISO will coordinate with the incoming Transmission Owner in the submittal of a FERC Filing, amending Attachment P (Listing of Grandfathered Agreements) of MISO’s Tariff to identify and classify the eligible GFAs to which the incoming Transmission Owner is a party. The incoming Transmission Owner should contact MISO’s Assistant General Counsel, to: (a) provide copies of any existing agreement(s) to be evaluated for potential eligibility for GFA treatment and (b) preliminarily discuss whether such agreement(s) would qualify for GFA treatment.

MISO’s Tariff defines GFAs as follows:
1.126 Grandfathered Agreement(s) (GFA): An agreement or agreements executed or committed to prior to September 16, 1998 or ITC Grandfathered Agreements that are not subject to the specific terms and conditions of this Tariff consistent with the Commission’s policies. These agreements are set forth in Attachment P to this Tariff.
1.30a Carved-Out GFA(s): Any Grandfathered Agreement(s) that the Commission has identified as “carved out” pursuant to Appendix B of the Commission’s September 16, 2004 order, Midwest Independent Transmission System Operator, Inc., 108 FERC ¶ 61,236 (2004) or that meet the criteria in Section 38.8.3(A).b, and set forth in Attachment P to this Tariff, as that Attachment may be amended from time to time.

The incoming Transmission Owner should also review Section 38.8.3(A) of MISO’s Tariff with respect to the treatment of GFAs after September 16, 2004, as well as the following FERC Orders:

- September 16, 2004 Order Addressing Treatment of GFAs in the Midwest ISO Energy Markets, and Establishing Hearing and Settlement Judge Procedures, 108 FERC ¶ 61,236 (2004) in Docket Nos. ER04-691-000, ER04-106-002 and EL04-104-000 (“GFA Order”).
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- April 15, 2005 Order on Rehearing and Compliance Filings Concerning the Treatment of GFAs in Midwest ISO Energy Markets, 111 FERC ¶ 61,042 (2005) in Docket Nos. ER04-691-001, ER04-106-003 and EL04-104-001, et al.

- December 15, 2009 Order on Tariff Revisions and Complaint, 129 FERC ¶ 61,221 at P 39 (2009), eliminating the availability of carved-out GFA status for existing agreements between the incoming Transmission Owner and its affiliates and/or owner-members, which is applicable to Transmission- Owning Members joining after December 15, 2009.

In addition, the incoming Transmission Owner is required to submit GFA templates to MISO’s Membership Services Department for any agreements eligible to be classified as GFAs. The GFA template identifies, among other information, the following:
 

• The GFA Responsible Entity (or the billing entity, in the case of Carved-Out GFAs).
• The GFA Scheduling Entity (or the entity responsible for scheduling, in the case of Carved-Out GFAs).
• The source and sink points applicable under the GFAs.
• The maximum MW Capacity permissible under the GFAs
• The GFA termination date or any indication that the GFA is evergreen.

The incoming Transmission Owner and MISO shall coordinate on MISO’s submittal of a Section 205 filing with FERC to update Attachment P of MISO’s Tariff, notifying FERC of any newly listed GFAs and applicable GFA treatment option(s). Please refer to MISO’s eTariff Filing Guidelines referenced above.

Newly added GFAs are afforded one of two treatment options (i.e., Option A or Option C). Newly added GFAs can choose: (1) Option A or C treatment; (2) carved out treatment, provided they meet applicable criteria; or (3) conversion of the agreements to transmission service under Module B of the Tariff. See, April 15,2005 Order on Rehearing and Compliance Filings Concerning the Treatment of GFAs in Midwest ISO Energy Markets, 111 FERC ¶ 61,042 at PP 104-106 and P 422 (2005).

Carved-Out GFAs are financially rather than “physically” carved-out of MISO’s markets, in accordance with Section 38.8.4 of the Tariff. FERC has recognized that such GFAs cannot be physically carved out of the market as if they were operating wholly “outside” the market.⁷ Carved-Out GFAs are financially exempt from congestion, losses and certain other charges directly linked to MISO’s markets, but bear responsibilities concerning reliability-related coordination, scheduling and real-time energy imbalances,⁸ and share in charges based on the system-wide reliability and efficiency benefits they receive from the existence and operation of the market.⁹ In addition, Carved-Out GFAs can participate in certain benefits offered by MISO’s markets. For example, parties to Carved-Out GFAs may use spot purchases and sales in the Energy Market,¹⁰ rather than scheduling under the Carved-Out GFAs, to readily obtain replacement power in case of outages, or to more economically meet load requirements. Both Carved-Out GFA parties and other Market Participants benefit from such flexibility, which results in market participation and more efficient commitment and dispatch of the generation that may be used to serve Carved-Out GFA Load.

⁷ See, Midwest Indep. Transmission Sys. Operator, Inc., 108 FERC ¶ 61,236 at P 90 (2004) (“September 16, 2004 Order”), order on reh’g, 111 FERC ¶ 61,042 at P 406, 415 (2005) (“April 15, 2005 Rehearing Order”),order on reh’g, 112 FERC ¶ 61,311 (2005) (“September 19, 2005 Rehearing Order”).

⁸ September 16, 2004 Order at PP 90, 144 (scheduling); April 15, 2005 Rehearing Order at PP 358-60 (scheduling), PP 373-74 (real-time imbalances), P 415 (coordination and scheduling); September 19, 2005 Rehearing Order at P 38 (scheduling and cooperation).

⁹ September 16, 2004 Order at PP 6, 297-98 (Schedule 17 charges); April 15, 2005 Rehearing Order at PP 174-181 (Schedule 10 and 17 charges), 419 (Schedule 18 charges); September 19, 2005 Rehearing Order at P 21 (Schedule 17 charges).

¹⁰ April 15, 2005 Rehearing Order at P 179; September 16, 2004 Order at PP 101, 191 (FERC expressed its expectation that one party to GFA No. 308 “will register with the Midwest ISO as a market participant so that if it ever needs to purchase energy in the Midwest ISO market, for an emergency or otherwise, it will be subject to the TEMT for those transactions”).

 

 1.  Financial Transmission Rights (“FTRs”)/Auction Revenue Rights (“ARRs”). Under MISO’s Tariff, an Annual ARR Allocation year consists of the period beginning on June 1 of a given calendar year to May 31 of the following calendar year. When the incoming Transmission Owner’s integration happens at mid-cycle, the Transmission Owner would not yet be able to participate fully in an Annual ARR Allocation. Accordingly, MISO’s Tariff provides the procedure for a Partial-Year FTR Allocation that would give the incoming Transmission Owner (or Customers taking service under the Transmission Owner’s tariff) a means to hedge congestion until the next Annual ARR Allocation year.

The Partial-Year FTR Allocation will be based on transmission rights arising from network, point-to-point and GFA transmission services in the incoming Transmission Owner’s service area. The components of these transmission rights will need to be timely registered with MISO in four ways: (1) transmission assets on which the rights are based should be registered in time for inclusion in the Network Model and Commercial Model updates immediately preceding the integration date;(2) entities claiming transmission rights should register as Market Participants;(3)the transmission services on which the rights are based should be incorporated into MISO’s Open Access Same-Time Information System (“OASIS”); and (4) the transmission rights must be recorded during a pre-integration, off-cycle ARR registration that will involve the preliminary gathering of data (relating to ARR Zone, Reserved Source Points, and transmission capacity), and the definition of ARR Entitlements that will form the basis for requests for FTRs in the Partial-Year FTR Allocation.

ARR Entitlements will be defined based on historical transmission usage during the Reference Year, which shall be the four full seasons before the integration date. As a part of this integration process, a Market Participant that has a sum total of baseload entitlement MWs below its baseload usage can invoke the supplemental rules to determine whether any new baseload entitlements can be created to fill the gap. The Partial-Year FTR Allocation will consist of a single round of nomination and allocation of FTRs, covering the peak and off-peak periods of each of the remaining seasons of the current Annual ARR Allocation period. The allocation of partial-year FTRs will be subject to the Simultaneous Feasibility Test (“SFT”). To the extent the paths of the partial-year FTRs may not coincide with actual usage, Market Participants may participate in the monthly FTR Auctions to reconfigure their FTR portfolio by selling and/or acquiring FTRs. Partial-year and monthly auction FTRs are also transferable on the FTR secondary market. For an incoming Transmission Owner, its “Year 1” of the allocation process will be the first full Annual ARR Allocation period that begins after the end of the partial year.
 

1. Capacity Market/Planning Resource Auction Participation Requirements. Under the MISO Tariff, the annual Planning Resource Auction (“PRA”) covers the MISO planning year period beginning on June 1 and running through May 31 of the following calendar year. Any Market Participant (“MP”) serving load and/or providing generation within the MISO footprint must participate in the annual PRA to demonstrate resource adequacy. An incoming MP that functions only as a Transmission Owner has no requirements within the capacity market and thus can disregard this section. As detailed in MISO BPM-011, Section 7, an incoming Transmission Owner that serves load and/or provides generation and does not join MISO within the normal auction preparation window will be provided the opportunity to take part in a Transitional PRA.

The responsibilities of the incoming MP in the Transitional PRA process are to provide MISO with coincident and non-coincident peak forecasts covering the transitional period, and to ensure that they have sufficient resources to meet their coincident peak load forecast plus a Planning Reserve Margin. If the incoming MP will only be providing generation, they will have the opportunity to offer their output into the Transitional PRA.

Incoming MPs with generation will be asked to provide test data for units expected to offer output into the Transitional PRA. This data forms the basis of the capacity credit that each unit will receive in order to submit offers into the auction.

1. Miscellaneous Agreements. The incoming Transmission Owner is required to provide any must run agreements, operating guides and/or other operating agreements governing the operation of facilities within the incoming Transmission Owner’s control area, to MISO’s Regional Manager of Reliability Coordination & Engineering, who will coordinate further review of such agreements within MISO Operations.

In addition, the incoming Transmission Owner is required to provide any interconnection agreements to MISO’s Resource Utilization Department to coordinate further review of such agreements within MISO Resource Planning.

1. Market Participation. Please note that Market Participant status is not a requirement for membership status. Rather, Market Participant status is required in order to interact with MISO’s Tariff (to buy and sell energy, bid and offer load and generation, participate in the FTR markets). This is substantially more involved than obtaining Membership status and requires establishing credit and executing a copy of Attachment W (Form of Market Participant Agreement) of MISO’s Tariff, which is a contractual commitment to the terms of MISO’s Tariff. If the incoming Transmission Owner also desires to be a Market Participant, it will be required to apply and register as such.

If the incoming Transmission Owner is not pursuing status as a Market Participant, it will be required to submit online a Non-Market Participant Application as discussed in Item 24(a). As a part of such application process, the Transmission Owner will designate various contacts, provide financial institution information, and also provide a valid client-side Digital Certificate that will be registered to the Transmission Owner’s Local Security Administrator (“LSA”).

2. Portal Access and Entity Code Registration with OATI.

a. Non-Market Participant Application.
First, the incoming Transmission Owner should: (i) obtain a Dun & Bradstreet D-UN-S Number (only if the entity does not already have one); (ii) obtain a digital certificate from one of the approved vendors listed on MISO’s website at https://www.misoenergy.org/markets-and- operations/mp-registration/market-participation/; and (iii) submit a Non-Market Participant Request for System Access form, which will provide the incoming Transmission Owner with access to the “Non-Market Participant Registration” online application.

Second, the incoming Transmission Owner must access MISO’s secure Market Portal to submit a fully executed “Non-Market Participant Registration” application. As a part of such application process, the Transmission Owner will designate various contacts, provide financial institution information, and also provide a valid client-side Digital Certificate that will be registered to the Transmission Owner’s Local Security Administrator (“LSA”).

b. OATI webRegistry.
The incoming Transmission Owner will be required to register their entity with Open Access Technology International, Inc.’s (“OATI”) webRegistry (https://www.naesbwry.oati.com/) as an Operating/Security Entity and obtain an Entity Code that is not already in use by MISO systems. If the incoming Transmission Owner has not already obtained Market Participant status, then it must also register its OASIS entity code as a Purchase Selling Entity and associated tagging desk code with the NAESB webRegistry hosted by OATI in order to purchase transmission and schedule Energy in the MISO Energy and Operating Reserve Market or with any transmission provider or market. Please note that such registration with OATI webRegistry is separate and distinct from registering as a MISO Transmission Owner or Market Participant.

Once both (i) the Transmission Owner’s Non-Market Participant Registration application has been received and processed by the Customer & Asset Registration Services Department and (ii) the Transmission Owner’s Membership Application have been approved by MISO’s Board of Directors, the Transmission Owner will be granted access to MISO systems. At that time, the LSA will be activated, resulting in the ability of the Transmission Owner to create portal user accounts with access to appropriate MISO Market Portal applications.

 

1. OATI Creation of a Link on MISO’s OASIS for the incoming Transmission Owner.

A new link shall be created by OATI on the MISO OASIS node for the incoming Transmission Owner. Each Transmission Owner has OASIS posting requirements by FERC, including the Transmission Owner’s rate calculation related information. The incoming Transmission Owner must first coordinate with OATI to register as a company in OATI OASIS (this registration in OASIS is separate and distinct from the webRegistry Entity Code registration referenced in Item 24(b) above). Thereafter, MISO will coordinate with OATI to coordinate the posting of OASIS information for the incoming Transmission Owner.

2. Transmission Owner OASIS Postings:
a. The incoming Transmission Owner is required to post rate calculation related information on MISO’s website on the link (created by MISO) to its OASIS information. When posting such information, please contact MISO’s IT Operations Center with the document(s) attached and include specific posting instructions. Please refer to the “Request for OASIS Postings documentation” located on the MISO OASIS at the following link:
https://www.oasis.oati.com/woa/docs/MISO/MISOdocs/Posting_to_OASIS.doc

b. The incoming Transmission Owner will also post notice of any future Transmission Service that it is migrating to the MISO’s Tariff. Any Transmission Service from the incoming Transmission Owner’s tariff should be posted on MISO’s OASIS.

1. MISO Model Updates. MISO maintains a Network Model in order to support various real-time and study network analysis functions used to maintain power system reliability, securely commit and dispatch generation, and operate the Day Ahead, Real Time, and FTR markets. The Network Model is populated with data provided by authorized Transmission Owners, Local Balancing Authorities, and Market Participants and provides a mathematical representation of the electric power system. All of MISO’s Transmission Owners are obligated to provide transmission equipment modeling information to MISO in accordance with NERC Reliability Standard IRO-010 and MISO RTO-SPEC-006. New and incoming Transmission Owners are required to submit substation one-line diagrams and geographic transmission maps of the Transmission Facilities it is transferring to MISO’s functional control to MISO’s Manager of Operations Modeling. Additional modeling data in the form of Common Information Model (CIM) files or other model data files from various power system applications may also be required. For more information, MISO’s BPM 010 for Network & Commercial Models and MISO’s Network & Commercial Model Update Schedule can be found on the public website.

2. Inter-Control Center Communications Protocol (ICCP) Set-up.
For real-time data requirements, MISO requires that an ICCP connection be established with the new Transmission Owner or an entity that they designate. This entity is required to have the required ICCP infrastructure. MISO is responsible for building out the communication network required as well as the monthly maintenance costs. For more information, please contact the Manager of Networking.

See the ICCP Data Requirements Business Practice Manual 031 for more information: BPM 031 – ICCP Data Requirements.