Southwest Power Pool REGIONAL TARIFF WORKING GROUP … meeting... · Central MCN in Zone 11....

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Southwest Power Pool REGIONAL TARIFF WORKING GROUP MEETING

November 15, 2018 Renaissance Tower – Dallas, Texas

• Summary of Motions and Action Items •

Agenda Item 3 – Consent Agenda – Motion by Tom Hestermann (Sunflower) seconded by Bernie Liu (Xcel) to approve the consent agenda. The motion passed unanimously.

Agenda Item 9 – RR 331 – Interchange Business Practice Clean Up – Motion by Heather Starnes (MJMEUC) seconded by Joel Hendrickson (Tri-State) to endorse RR 331 with the RTWG’s suggested edits. The motion passed unanimously.

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Southwest Power Pool REGIONAL TARIFF WORKING GROUP MEETING

November 15, 2018 Renaissance Tower – Dallas, Texas

• M I N U T E S •

Agenda Item 1 – Administrative Items SPP Chair David Kays (OGE) called the meeting to order at 8:30 a.m. The following members were in attendance or represented by proxy:

David Kays Oklahoma Gas & Electric Company Robert Pick Nebraska Public Power District Mo Awad KCP&L and Westar, Evergy Companies Michael Billinger Midwest Energy Inc. James Bixby ITC Great Plains, LLC Alfred Busbee GDS Associates/East Texas Electric Cooperatives Tom Christensen Basin Electric Power Cooperative Jack Clark NextEra Energy Resources Alex Dobson Oklahoma Municipal Power Authority Terri Gallup American Electric Power Greg Garst Omaha Public Power District Joel Hendrickson Tri-State Generation and Transmission Tom Hestermann Sunflower Electric Power Corporation Bernie Liu Xcel Energy Brandon McCracken Western Farmers Electric Cooperative Jessica Meyer Lincoln Electric System Neil Rowland Kansas Municipal Energy Agency Steve Sanders Western Area Power Administration – UGPR Robert Shields Arkansas Electric Cooperative Corporation Heather Starnes Healy Law Offices/Missouri Joint Municipal Electric Utility Commission John Stephens City Utilities of Springfield Todd Tarter Empire District Electric Company

The following proxies were recorded: Heather Starnes (MJMEUC) for Alex Dobson (OMPA) Emily Brown (AEP) for Terri Gallup (AEP) – as needed (Attachment 1a – 2018 11 15 RTWG In Person Attendance) (Attachment 1b – 2018 11 15 RTWG WebEx Attendance)

Agenda Item 2 – Review of Past Action Items Action Item 87 was closed.

Agenda Item 3 – Consent Agenda (Approval Item) David Kays (OGE) presented the consent agenda which consisted of the October 22, 2018 minutes, October 25, 2018 minutes, and one market revision request (RR 326). Motion by Tom Hestermann

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(Sunflower) seconded by Bernie Liu (Xcel) to approve the consent agenda. The motion passed unanimously.

Agenda Item 4 – RTWG Task Force Updates – CPTF & BDTF There were no new updates for either of the two RTWG task forces.

Agenda Item 5 – RRR Update Denise Martin (SPP) provided the RRR update. November 2018 will be updated for the addition of South Central MCN in Zone 11. December 2018 will include a Z2 update. January 2019 will be updated with the annual update for approximately 20 TOs. For November 2018 through January 2019, the following will be posted: the Original RRR file, the new RRR Automation Output file, and a Formulas Only RRR file.

Agenda Item 6 – Settlements Update Steve Davis (SPP) provided an update on Settlements involvement in responding to the deficiency letter SPP received regarding the FERC Order 844 compliance filing. Settlements has begun assessing the system changes necessary to implement the upcoming FERC Order 841 compliance filing. Member testing will be starting soon on the Settlement Replacement Project. As a reminder, for all questions and updates regarding the Settlement Replacement Project, please contact your CWG representative or Dana Boyer (SPP).

Agenda Item 7 – Legal Update Joe Ghormley (SPP) provided the legal update using the October 2018 Regulatory Status Report and Regulatory Outlook as the baseline (http://www.spp.org/spp-documents-filings/?id=18504). A brief overview of each filing made since the latest publication was given, as well as an overview of a complaint filed with FERC by AWEA and the Wind Coalition.

Agenda Item 8 – MWTG RR Update Nicole Wagner (SPP) provided an update to let the group know the revision requests related to Mountain West will be withdrawn and closed. The revision requests were not voted on by the RTWG, and no action is needed to close the revision requests.

Agenda Item 9 – RR 331 – Interchange Business Practice Clean Up (Approval Item) Shari Brown (SPP) introduced a revision request to clarify and reorganize current Interchange Tagging Business Practices making them easier to use and understand. Additional changes are being made to change references from NERC to NAESB where applicable. The group reviewed the proposed redlines and suggested multiple non-substantive edits. Motion by Heather Starnes (MJMEUC) seconded by Joel Hendrickson (Tri-State) to endorse RR 331 with the RTWG’s suggested edits. The motion passed unanimously. (Attachment 2 – RR 331 Recommendation Report)

Agenda Item 10 – RR 336 – Generator Ride Through (Approval Item)

Jason Tanner (SPP) introduced proposed tariff changes to Attachment V under Appendix C and Appendix G to the GIA to correct an error from SPP’s FERC Order 827 compliance filing, remove outdated language from FERC Order 661, and add momentary cessation requirements. The RTWG

http://www.spp.org/spp-documents-filings/?id=18504

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expressed concern that the proposed redlines did not match the intent of what was being described by SPP during the discussion. RTWG comments will be submitted documenting the concerns and containing revisions that are the start of an attempt to reduce confusion and also to use Tariff terminology. The RTWG remanded the revision request back to SPP.

Agenda Item 11 – SPP Stakeholder Prioritization Process Terry Rhoades (SPP) provided an overview of the SPP Stakeholder Prioritization Process. Timelines and steps included in the Quarterly Enhancement and Quarterly Project Processes were detailed. Metrics for Enhancements and RRs from 2015 through 2018 were reviewed along with results from the 2017 survey that was provided to the MWG, RTWG, CWG, ORWG, BPWG and CPWG. The group was encouraged to continue to be involved with the process.

Agenda Item 12 – RR 234 – Firm Redirect Pricing Steve Davis (SPP) brought a presentation to the group detailing SPP comments submitted on November 8, 2018 to RR 234. RR 234, as approved by RTWG on July 19, 2017, was originally developed to facilitate the development of a secondary market for firm transmission service and to help provide consistency of revenue to the TOs. SPP believes the proposed revisions may not be defensible at FERC, may harm TOs for Firm usage, and contradict multiple existing Tariff provisions and North American Energy Standards Board standards. SPP also believes existing Tariff provisions allow for the stated desired result through bilateral agreements. Given the length of time from approval of RR 234 to the submission of the SPP comments, the RTWG requested a reeducation of the original proposal in order for the group to make a well informed decision.

Agenda Item 13 – RR 335 – Generation Interconnection Three-Stage Study Process Marisa Choate (SPP) introduced the SPP comments that were submitted on November 8, 2018. These comments to show the three phase Generator Interconnection study process redlined against current effective Tariff language, and no longer include what was anticipated to be pending language for FERC Order 845 compliance since that order is now on hold. This version will serve as the baseline for review going forward. Chris Cranford (SPP) resumed the review of redlines and noted that edits made based on direction provided during the November 7, 2018 RTWG meeting and accepted Tradewind Energy comments were highlighted in yellow. The group worked to edit the revision request through Section 4. The intention is to complete the review and take action at the next scheduled meeting.

Agenda Item 14 – Working Group Survey Chris Cranford (SPP) provided the QR code and link for this month’s survey and it will also be include in the recap email that is sent on Friday.

Agenda Item 15 – Review of Motions, Action Items, and Future Meetings The next scheduled RTWG meeting is a net conference November 29, 2018 (9:00 a.m. – 12:00 p.m.) and (1:00 p.m. – 4:00 p.m.). Respectfully Submitted, Chris Cranford on behalf of Marisa Choate Secretary

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Attachments (Attachment 1a – 2018 11 15 RTWG In Person Attendance) (Attachment 1b – 2018 11 15 RTWG WebEx Attendance) (Attachment 2 – RR 331 Recommendation Report)

Name Email

Alfred Busbee [email protected]

Andrea Harrison (WFEC) [email protected]

Brandon McCracken (WFEC) [email protected]

Brenda Fricano [email protected]

Brent Hebert [email protected]

Chris Nolen [email protected]

Christy Marske(OGE) [email protected]

Denise Martin (SPP) [email protected]

Derek Sunderman [email protected]

Don Frerking (KCPL Westar) [email protected]

Emily Brown (AEP) [email protected]

Grant Wilkerson [email protected]

Greg Garst (OPPD) [email protected]

Heather Starnes (MJMEUC) [email protected]

Isaac Stroup (OCC) [email protected]

J.P. Maddock [email protected]

Jason Mazigian (BEPC) [email protected]

Jason Tanner (SPP) [email protected]

Jessica Meyer (LES) [email protected]

Jim Bixby [email protected]

Jim Hotovy [email protected]

John Luallen (SPP) [email protected]

John Stephens [email protected]

Ken Quimby [email protected]

Kristen Darden (SPP) [email protected]

Lee Elliott [email protected]

Mark Whitson (SPP) [email protected]

Matt Welch [email protected]

Mo Awad [email protected]

Nicole Wagner (SPP) [email protected]

Robert Pick (NPPD) [email protected]

Robert Safuto (Customized Energy Solutions) rsafuto@ces‐ltd.com

Robert Shields [email protected]

Rodney Massman [email protected]

Ron Thompson (NPPD) [email protected]

Shari Brown [email protected]

Terri Gallup (AEP) [email protected]

Terry Rhoades [email protected]

Tessie Kentner [email protected]

Todd Tarter (Liberty‐EDE) [email protected]

Tom Christensen [email protected]

Walt Cecil [email protected]

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Revision Request Recommendation Report

RR #: 331 Date: 10-1-2018

RR Title: Interchange Business Practice Clean Up

SUBMITTER INFORMATION

Submitter Name: Shari Brown Company: Southwest Power Pool

Email: [email protected] Phone: 501-614-3236

EXECUTIVE SUMMARY AND RECOMMENDATION FOR MOPC AND BOD ACTION

To be completed upon Working Group approval

OBJECTIVE OF REVISION

Objectives of Revision Request: Timing statement clarification for when Firm tags must actually be received.

The original division of denial criteria was divided between BP 5200 and BP5300. Prior to the IM, SPP was the “Scheduling

Agent/Entity” per a legal agreement for our member Balancing Authorities. BP 5300 was intended to explain items for denial of

schedules for our members. As changes have been added they have not been added consistently between 5200 and 5300. It was

hard for the customer to understand the difference between the intended purpose of BP 5200 and BP 5300.

BP 5350 Emergency Tags was instructions on Emergency tags if the SPP Scheduling Entity assisted the old Legacy BA in getting

an Emergency Tag. That practice is no longer necessary since SPP became the only BA for the footprint. Business Practices still

reference NERC even though Interchange Standards have been retired and moved to NAESB Business Practices.

Changes are intended to clarify and reorganize current Interchange Tagging Business Practices to make them easier for the use and

understanding of the customer.

SPP STAFF ASSESSMENT

To be completed upon Working Group approval

IMPACT

Will the revision result in system changes No Yes

Summarize changes:

Will the revision result in process changes? No Yes

Summarize changes:

Is an Impact Assessment required? No Yes

If no, explain:

Estimated Cost: $ Estimated Duration: months

Primary Working Group Score/Priority:

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SPP DOCUMENTS IMPACTED

Market Protocols Protocol Section(s): Protocol Version:

Operating Criteria Criteria Section(s): Criteria Date:

Planning Criteria Criteria Section(s): Criteria Date:

Tariff Tariff Section(s):

Business Practice Business Practice Number: 5050, 5200, 5250, 5300, 5400, 5450, 6150

Integrated Transmission Planning (ITP)

Manual Section(s):

Revision Request Process Section(s):

Minimum Transmission Design

Standards for Competitive Upgrades (MTDS) Section(s):

Reliability Coordinator and Balancing

Authority Data Specifications (RDS) Section(s):

SPP Communications Protocols Section(s):

WORKING GROUP REVIEWS AND RECOMMENDATIONS

List Primary and any Secondary/Impacted WG Recommendations as appropriate

Primary Working Group: BPWG

Date: 10/22/2018

Action Taken: Approved

Abstained: None

Opposed: None

Secondary Working Group: RTWG

Date: 11/15/2018

Action Taken: Approved with grammatical changes

Abstained: None

Opposed: None

Secondary Working Group:

Date: ORWG

Action Taken:

Abstained:

Opposed:

Reasons for Opposition:

Secondary Working Group: TWG

Date: 11/12/2018

Action Taken: Approved

Abstained: None

Opposed: None

MOPC

Date: Jan 2019

Action Taken:

Abstained:

Opposed:


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BOD/Member Committee

Date: N/A

Action Taken:

Abstained:

Opposed:


COMMENTS

Comment Author:

Date Comments Submitted:

Description of Comments:

Status:

Comment Author:

Date Comments Submitted:

Description of Comments:

Status:

PROPOSED REVISION(S) TO SPP DOCUMENTS

SPP Business Practices

5050 TagSchedule Timing Requirements

(return to TOC)

SPP requirements for submission and processing of schedules are listed in Attachment P to the SPP

OATT1.

Business Practice

Schedules for all Firm transmission service have a submission deadline of no later than 1200-day prior.

A late Firm Schedule will be allowed even if the unscheduled Firm has been sold on a Non-Firm basis.

The Late Firm Schedule must be received at least 45 minutes1 hour prior to start to displace Non-Firm.2.

All schedules tags must be evaluated and approved within the timelines listed for NAESBERC Tag

Specificationstagging and SPP Business Practices. Those timing requirements are:

1 SPP OATT Attachment P - http://www.spp.org/eTariff.asp 2 SPP Business Practice 5250 – see Late Schedules

http://www.spp.org/eTariff.asp

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Hourly tTags submitted one hour or less prior to the start must be evaluated in ten minutes. Hourly

tTags submitted more than an hour but less than four hours prior to start must be evaluated in 20

minutes.

Tags of duration less than 24 hours that are submitted four hours prior or more prior to start must

be evaluated in two hours.

Tags of duration 24 hours or more must be evaluated in two hours.

TagsSchedules that have not been approved within the NAESB Business PracticeNERC approval and

SPP Business Practice timing requirements will result in a passive denial as per NAESBERC Tag

Specificationstagging requirements.

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5200 Tag Denial Criteria for Inappropriate Use of Transmission Service (return to TOC)

SPP validates all tags against the referenced reservation/s.

Business Practice

SPP will deny a tag as incorrect for the following reasons:

Incomplete fields for required information per the latest NAESBERC E-Tag specification

The referenced SPP OASIS reservation does not exist or is not CONFIRMED

The referenced SPP OASIS reservation is not CONFIRMED

SWPP is not listed in the CA column on the tag for each SWPP reservation referenced for Import and

Export tags.

The Transmission Product Code(s) on the tag does not match the Reservation(s)

The Tag’s Start / Stop times do not fit within the Reservation’s date / time

Scheduled capacity exceeds reserved capacity, including all tags scheduled against the reservation

Redirected service without a reservation

POR / POD on the tag does not match POR/POD on the reservation

The tag failed Market Entity validation for any SPP market participant. (SPP sources and/or sinks that

are not properly mapped to a market participant settlement location.)

SPP may deny a tag if the source / sink on the tag does not match the source / sink on the reservation3

SPP may deny a tag if it is incomplete (amount not specified).

SPP may deny a tag if it is late4.

3 SPP Business Practice 2150 – see Valid Reservation Source / Sink 4 SPP Business Practice 5250 – see Late Schedules

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5250 Late Schedules (return to TOC)

Attachment P to the SPP OATT79 lists the time requirements for initial submission of energy schedules,

and changes to schedules. Any schedule submitted after the OATT Attachment P timing requirements,

as modified in Business Practice 5050, is considered late.

__________________________________________________________________________________

Business Practice

Schedules are due 20 minutes prior to the implementation of the schedule. Tags received less than 20

minutes prior to the implementation of the schedule will be considered late and will generally be denied.

Subject to the sole discretion of the SPP Reliability Coordinator, late tags may be accepted for system

reliability reasons. These exceptions will be posted the next day with the following information: Tag ID,

reason for exception and PSE that created the tag.

SPP will approve a late schedule for Firm service although the unscheduled firm transfer capability has

already been sold on a Non-Firm basis if the Late Firm Schedule is received at least 45 minutes1 hour

prior to start.

If displacement of Non-Firm is required, the curtailment will be done according to NERC TLR

procedures. If schedules indicate that the SOL of any flowgate will be exceeded, NERC TLR

will be called to relieve the overload. The NERC TLR process includes curtailments across the

DC Ties. However, SPP may or may not use the NERC IDC to facilitate curtailment of DC Tie

Schedules

For DC Ties or Contract Limit Paths

ATC for the next day that is made available due to unscheduled Firm reservations will be sold as Non-

Firm service beginning at 1000 of each day. Firm schedules submitted after 1000 the day prior but by

hh:15 of the hour prior to start, may cause a DC tie or contract path to be oversold and Non-Firm service

that has been scheduled to be displaced.

If the displacement of Non-Firm schedules is required, displacement will be done using the same

procedures, as a NERC TLR. Schedules will be curtailed on a pro-rata basis, beginning with the

schedules using the lowest NERC priority reservations, until the DC tie or contract path limit is no

longer exceeded.

Non-Firm schedules using higher NERC priority reservations that displace schedules using lower NERC

priority reservations will be processed in the same manner as Firm schedules displacing Non-Firm

schedules. If displacement of service is required by the submission of Non-Firm schedules, the

schedules must be submitted by hh:15 of the hour prior to start. Schedules submitted after hh:15 of the

hour prior to start will be processed for approval if practicable. If schedules are curtailed due to being

displaced by a schedule using a higher NERC priority reservation, only the amount curtailed will be

recalled from the reservation. The tag curtailed by the SWPP TP will serve as the notification to the

operator of the DC tie and the PSE of the curtailments.


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5300 TagSchedule Denial Criteria for Inappropriate Balancing Authority or Integrated Marketplace Transactions

(return to TOC)

SPP validates all tagsschedules to ensure that SPP is included as the scheduling entity where

appropriate, as well as other reasons.

Business Practice

SPP will deny a tagschedule as incorrect for the following reasons:

The schedule does not meet any of the requirements stated in Business Practice 5200- Tag Denial

Criteria for Inappropriate Use of Transmission Service.

SPP is not included as a scheduling entity in the tag Physical Ppath section for any

transactionschedule using SPP Transmission service.

SPP is not listed in the BA column of the tag Physical Path section for Import or Export tags.

SPP is not included as a scheduling entity between SPP and any other Balancing Authority/first

tier, such as WECC, MISO, and ERCOT. SPP is not included as a scheduling entity in the Physical

path for any schedule into, through or out of the SWPP BA.

If the START or STOP times for any Day Ahead Market Import, Export, or Through Interchange

Transaction schedule profile are submitted in the :51 -:59 or :01 - :09 periods. Available times will

be at the top of the hour or any other time outside of the: 51 - :59 or :01 - :09 periods of the hour.

If the submitted ramp duration from the START or STOP of any schedule profile is less than the

duration of the schedule profile.

The tag failed Market Entity validations for any SPP Market Participant. (SPP sources and/or

sinks that are not properly mapped to a Market Participant settlement location.)

SPP may deny a tag if it failed for insufficient ramp.

SPP may deny a tag if it is late.

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5400 Tag Cancellation, Termination, Withdrawal or Correction (return to TOC)

Business Practice SPP, acting in the Balancing Authority Scheduling Entity or Tariff Administration capacities, does not have the

capability to cancel, terminate, withdraw or correct a tag. These actions must be done by the PSE5. SPP may

request such actions be taken when a tag is in error under the following circumstances:

SPP has incorrectly approved the tag. An SPP member with approval rights has incorrectly approved the tag. At least one of the reservations used on the tag is in error. SPP or an SPP member with approval rights has denied a tag/schedule within scheduling timing rules, but

the tag was implemented under tagging rules.

If the PSE does not comply with the request made by SPP, SPP may take further action including curtailment of the

tag.

5 NERC Appendix 3D - http://reg.tsin.com/Tagging/e-tag/e-tag-spec-v-18-20071107.doc

http://reg.tsin.com/Tagging/e-tag/e-tag-spec-v-18-20071107.doc

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5450 Loss Provision Requirements for Network Integration Transmission Service (return to TOC)

Business Practice

Self-provided losses are no longer allowed for any tags in the Integrated Marketplace per Tariff.

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6150 Abnormal Conditions Procedures (return to TOC)

SPP administers reservations and schedules at certain points on the system which have specific capacity

and transmission limitations. Such points include, but are not specifically limited to, DC Ties, tie line

limitations, first tier interfaces and various paths with capacity and transmission limitations. Stated

limitations are due to operational restrictions and must be maintained for reliability of the bulk electric

system. The stated or contractual limit may require modification due to changes associated with on-line

generation and/or transmission system topology.

Business Practice

There are various procedures that may be implemented in order to maintain system reliability during an

abnormal condition.

Transmission Loading Relief (TLR) - When the observed loading on a Flowgate approaches an

SOLi or IROL, the SPP Reliability Coordinator, at his discretion, may elect to initiate the NERC

TLR procedureii. Upon the initiation of the TLR, the involved Flowgate will be activated (if not

already activated) in the SPP Market Operating System (MOS) and appropriate physical

transactions and market schedules will be curtailed (via Interchange Distribution Calculator

(IDC) and Curtailment and Adjustment Tool (CAT) on a pro-rata basis to return the Flowgate

loading to an acceptable level.

Transmission Service Provider (TSP) - When the stated or contractual limit requires modification

due to conditions on the bulk electric system, the Transmission Operator will normally notify

SPP of the circumstances surrounding the required modification. Concurrently the SPP Shift

Engineer and Reliability Coordinator will become aware of the circumstances through their real

time monitoring systems. The Transmission Operator will inform SPP of any new limits

resulting from such an event. The SPP Reliability Coordinator and SPP Shift Engineer will input

the modified parameters into the production system. Schedule adjustments will be done by the

TSP, when feasible, when stated limitations are exceeded causing an oversale condition due to

operational changesiii. Schedule adjustments or TSP curtailments will be based on NERC priority

beginning with the lowest priority. If more than one schedule is active using the same NERC

priority level, the adjustments or TSP curtailments will be done on a pro-rata basis following the

same procedure used when a NERC TLR is issued. If only one customer is impacted and that

one customer has multiple schedules that can be adjusted, the customer may be given the option

to achieve the necessary relief by adjusting the schedule/s of their choice instead of pro-rata

curtailments being done. These schedule adjustments or TSP curtailments could impact all

schedules up to and including Firm (F-7) schedules, if necessary. When transactions are required

to be adjusted or curtailed, the impacted customer or PSE should receive notification from the

SPP Tariff Administrator.

Congestion Management Event (CME)iv – During an event that causes a change in the SOL or IROL,

the SPP Reliability Coordinator and SPP Shift Engineer will evaluate the current flow with regards to

the new SOL or IROL. If the current schedules and/or system flows are above the new limit, the SPP

Reliability Coordinator, at his discretion, may elect to initiate the NERC TLR procedure to reduce

applicable schedules and/or flows. Schedule adjustments may also be effected through Transmission

Service Provider curtailment or voluntary schedule adjustment by the Transmission Customer. The

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method of schedule adjustment is established by the timing of and urgency required by specific events

and the nature of the congestion experienced. Appropriate action will be determined by examining the

profile and nature of current schedules.

Explanation / Rationale

This Business Practice is intended to be general information for SPP customers and may not include

all SPP processes or procedures that may be implemented during an abnormal condition.

i. The SPP Reliability Coordinator has the responsibility and authority to address a potential or

actual SOL or IROL, per current NERC sStandards IRO-006-4.1.

ii. A Transmission Operator and Transmission Customer has the responsibility to address a potential

or actual SOL or IROL, per current NERC sStandards IR0-006-4.1

iii. The Transmission Service Provider (SPP) has the responsibility and authority to curtail

schedules, up to and including Firm schedules, when an emergency or unforeseen condition

impairs or degrades the reliability of the Transmission System, per Section 13.6 of the SPP Tariff.

SPP Business Practice 1500 outlines the RTO Tariff Administrator’s responsibility and authority

to curtail schedules following an outage on the SPP AC system.

iv. Congestion Management Event is described in section 6.8 of the SPP Market Protocols, Schedule

Curtailment/Adjustment under SPP Congestion Management














http://www.nerc.com/files/IRO-006-4.1.pdf

http://www.nerc.com/files/IRO-006-4.1.pdf

http://www.spp.org/publications/SPP_Tariff.pdf

http://www.spp.org/publications/SPP_Business_Practices_2010_07_013%20%20w_RevHis.pdfhttp:/www.spp.org/publications/SPP_Business_Practices_2010_07_013%20%20w_RevHis.pdf

http://www.spp.org/publications/Mkt_Protocols_19.0.doc

Southwest Power Pool REGIONAL TARIFF WORKING GROUP … meeting... · Central MCN in Zone 11....

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