March 30, 2021 the Honorable Kimberly D. Bose Secretary Federal

March 30, 2021

The Honorable Kimberly D. Bose Secretary Federal Energy Regulatory Commission 888 First Street NE Washington, DC 20426

RE: Southwest Power Pool, Inc., Docket No. ER21-___ Submission of Network Integration Transmission Service Agreement and Network Operating Agreement

Dear Secretary Bose:

Pursuant to section 205 of the Federal Power Act, 16 U.S.C. § 824d, and section 35.13 of the Federal Energy Regulatory Commission’s (“Commission”) regulations, 18 C.F.R. § 35.13, Southwest Power Pool, Inc. (“SPP”) submits: (1) an executed Service Agreement for Network Integration Transmission Service (“Service Agreement”) between SPP as Transmission Provider and Evergy Metro, Inc. (“Evergy Metro”) as Network Customer (“Twenty-Third Revised Evergy Metro Service Agreement”); and (2) an executed Network Operating Agreement (“NOA”) among SPP as Transmission Provider and Evergy Metro as Network Customer, and Evergy Metro, Evergy Missouri West, Inc. (“Evergy Missouri”), and Evergy Kansas Central, Inc. (“Evergy KS”) as Host Transmission Owners (“Twenty-Third Revised Evergy Metro NOA”).1 The Twenty-Third Revised Evergy Metro Agreements modify and supersede the Service Agreement and NOA among the Parties accepted by the Commission in Docket No. ER21-482-000.2 SPP

1 The Twenty-Third Revised Evergy Metro Service Agreement and Twenty- Third Revised Evergy Metro NOA are referred to collectively as the “Twenty-Third Revised Evergy Metro Agreements,” and SPP, Evergy Metro, Evergy Missouri, and Evergy KS are referred to as the “Parties.” The Twenty-Third Revised Evergy Metro Agreements are designated as “Twenty-Third Revised Service Agreement No. 1276.”

2 See Sw. Power Pool, Inc., Letter Order, Docket No. ER21-482-000 (Jan. 22, 2021) (“January Order”). The Service Agreement and NOA referenced in the January Order are referred to collectively as the “Twenty-Second Revised Evergy Metro Agreements” and individually as the “Twenty-

The Honorable Kimberly D. Bose March 30, 2021 Page 2

is submitting this filing because the Twenty-Third Revised Evergy Metro Agreements include terms and conditions that do not conform to the standard form of service agreements set forth in the SPP Open Access Transmission Tariff (“SPP Tariff”).3

I. Description of the Twenty-Third Revised Evergy Metro Agreements

Since the January Order, the Parties revised the Twenty-Second Revised Evergy Metro Service Agreement to update Appendix 1. The Twenty-Second Revised Evergy Metro Service Agreement was also updated to include changes to the pro forma Service Agreement approved by the Commission in Docket No. ER20-418.4 To facilitate these changes, the Parties executed the Twenty-Third Revised Evergy Metro Service Agreement, which is submitted herein with the Twenty-Third Revised Evergy Metro NOA.

II. Non-Conforming Terms and Conditions

The Twenty-Third Revised Evergy Metro Service Agreement retains the non-conforming terms and conditions in Sections 2.0 and 3.0; Sections 8.1, 8.6, and 8.9 of Attachment 1; Appendix 3; Appendix 4; Attachment A and Attachment B from the Twenty-Second Revised Evergy Metro Service Agreement. The Twenty- Third Revised Evergy Metro NOA retains the non-conforming terms and conditions in Sections 13.0 and 17.0 from the Twenty-Second Revised Evergy Metro NOA.5 These non-conforming terms and conditions were accepted by the Commission in the January Order.6

Second Revised Evergy Metro Service Agreement” and “Twenty-Second Revised Evergy Metro NOA”.

3 See Southwest Power Pool, Inc., Open Access Transmission Tariff, Sixth Revised Volume No. 1 at Attachment F (“pro forma Service Agreement”) and Attachment G (“pro forma NOA”), collectively “the pro forma Agreements.”

4 Sw. Power Pool, Inc., Letter Order, Docket No. ER20-418-000 (Feb. 6, 2020).

5 The non-conforming terms and conditions are highlighted in Exhibit No. SPP-1.

6 See January Order. The Honorable Kimberly D. Bose March 30, 2021 Page 3

III. Effective Date and Waiver

SPP requests an effective date of March 1, 2021, for the Twenty-Third Revised Evergy Metro Agreements. To permit such an effective date, SPP requests a waiver of the Commission's 60-day notice requirement set forth at 18 C.F.R. § 35.3. Waiver is appropriate because the Twenty-Third Revised Evergy Metro Agreements are being filed within 30 days of the commencement of service.7

IV. Additional Information

A. Information Required by Section 35.13 of the Commission’s Regulations, 18 C.F.R. § 35.13:

(1) Documents submitted with this filing:

In addition to this transmittal letter, SPP includes the following:

(i) A clean copy of the Twenty-Third Revised Evergy Metro Agreements;

(ii) A redlined copy of the Twenty-Third Revised Evergy Metro Agreements; and

(iii) Exhibit No. SPP-1 – Highlighted pages of non-conforming terms and conditions in the Twenty-Third Revised Evergy Metro Agreements.

(2) Effective Date:

As discussed herein, SPP respectfully requests that the Commission accept the Twenty-Third Revised Evergy Metro Agreements with an effective date of March 1, 2021.

7 See Prior Notice and Filing Requirements Under Part II of the Federal Power Act, 64 FERC ¶ 61,139, at 61,983-84, order on reh’g, 65 FERC ¶ 61,081 (1993) (the Commission will grant waiver of the 60-day prior notice requirement “if service agreements are filed within 30 days after service commences.”); see also 18 C.F.R. § 35.3(a)(2). The Honorable Kimberly D. Bose March 30, 2021 Page 4

(3) Service:

SPP is serving a copy of this filing on the Parties listed in the Twenty-Third Revised Evergy Metro Agreements.

(4) Basis of Rate:

All charges for the Twenty-Third Revised Evergy Metro Agreements will be determined in accordance with the SPP Tariff and the Twenty-Third Revised Evergy Metro Agreements.

B. Communications:

Any correspondence regarding this matter should be directed to:

Justin A. Hinton Nicole Wagner Attorney Manager - Regulatory Policy Southwest Power Pool, Inc. Southwest Power Pool, Inc. 201 Worthen Drive 201 Worthen Drive Little Rock, AR 72223 Little Rock, AR 72223 Telephone: (501) 482-2468 Telephone: (501) 688-1642 [email protected] [email protected]

Tessie Kentner Managing Attorney Southwest Power Pool, Inc. 201 Worthen Drive Little Rock, AR 72223 Telephone: (501) 688-1782 [email protected]

V. Conclusion

For all the foregoing reasons, SPP respectfully requests that the Commission accept the Twenty-Third Revised Evergy Metro Agreements with an effective date of March 1, 2021.

Respectfully submitted,

/s/ Justin A. Hinton Justin A. Hinton The Honorable Kimberly D. Bose March 30, 2021 Page 5

Attorney Southwest Power Pool, Inc. 201 Worthen Drive Little Rock, AR 72223 Telephone: (501) 482-2468 [email protected]

Attorney for Southwest Power Pool, Inc.

Exhibit No. SPP-1 Non-Conforming Language Exhibit No. SPP-1

Non-Conforming Language in the Network Integration Transmission Service Agreement 2.0 The Network Customer agrees to take and pay for Network Integration Transmission Service in accordance with the provisions of Parts I, III and V of the Tariff and this Service Agreement with attached Specifications and subject to the provisions of the Agreement for the Provision of Transmission Service to Missouri Bundled Retail Load (“Missouri Agreement”). 3.0 The terms and conditions of such Network Integration Transmission Service shall be governed by the Tariff, as in effect at the time this Service Agreement is executed by the Network Customer, or as the Tariff is thereafter amended or by its successor tariff, if any. The Tariff as it currently exists, or as it is hereafter amended is incorporated in this Service Agreement by reference. In the case of any conflict between this Service Agreement and the Tariff, the Tariff shall control except as provided in the Missouri Agreement. The Network Customer has been determined by the Transmission Provider to have a Completed Application for Network Integration Transmission Service under the Tariff. The completed specifications are based on the information provided in the Completed Application and are incorporated herein and made a part hereof as Attachment 1.

ATTACHMENT 1 TO THE NETWORK INTEGRATION TRANSMISSION SERVICE AGREEMENT

BETWEEN SOUTHWEST POWER POOL, INC. AND EVERGY METRO, INC. SPECIFICATIONS FOR NETWORK INTEGRATION TRANSMISSION SERVICE

8.1 Transmission Charge Monthly Demand Charge per Section 34 and Part V of the Tariff shall be treated pursuant to the Missouri Agreement.

8.6 Real Power Losses – Distribution For Delivery Points on Evergy Kansas Central, Inc. Network System: The Network Customer shall replace all distribution losses in accordance with Evergy Kansas Central, Inc.'s Open Access Transmission Tariff, Section 28.5, based upon the location of each delivery point meter located on distribution facilities. The composite loss percentages in Section 28.5 shall exclude transmission losses.

8.9 Wholesale Distribution Service Charge For Delivery Points on Evergy Kansas Central, Inc. Network System: The Wholesale Distribution Service Charge cost support and monthly charge is detailed in Appendix 4.

APPENDIX 3

Evergy Missouri West, Inc. Eve and Richards, MO Delivery Points

(a) (b) (c) (d) (e) SPP Bus Delivery Point of Meter Ownership Meter Voltage Number / Point Delivery [kV] Measured Name Name Voltage (Location) [kV] (1) (2) 533635 City of 12.5 Evergy Kansas Central, Inc. 12.5 FTSCOTT2 Eve, MO (Circuit)/(d) 69 kV 533635 City of 12.5 Evergy Kansas Central, Inc. 12.5 FTSCOTT2 Richards, (Circuit)/(d) 69 kV MO

FOOTNOTES: (1) kV value where meter is physically located. (Location) = Meter located on Distribution. (Low Side) = Low Side of Transformer, (Bus) = Meter located on distribution bus after switch or voltage regulator, and (Circuit) = Meter located on distribution circuit. After September 1, 2012, the applicable Loss Factor, from the Loss Factor tables included in Section 28.5 of Evergy Kansas Central, Inc.’s OATT, are identified as (a) through (h) in the Notes column of those tables. Any special configuration not represented in (a) through (h) will be outlined as a special footnote within this appendix. (2) The Points of Delivery under this NITSA are located at, or immediately adjacent to, the connection between Evergy Kansas Central, Inc.’s facilities and the Network Customer’s facilities. Distribution Network.

Appendix 4 Wholesale Distribution Service Charge Calculations

APPENDIX 4

Evergy Missouri West, Inc. Wholesale Distribution Service Charge July 2019

Delivery Point Facility Facility Cost Facility Facility Cost Metered Loss Share of Facility MW Per MW MW Adjusted Cost Demand Demand MW Demand Richards Circuit SK7217 12-04 $357,563.30 6.2000 $57,671.50 0.0870 0.0888 $5,122.28 Sub SK7217 Fort Scott $146,066.60 9.6000 $15,215.27 0.0870 0.0888 $1,351.39 Eve Circuit SK7217 12-04 $162,502.14 6.2000 $26,210.02 0.1142 0.1166 $3,055.74 Sub SK7217 Fort Scott $146,066.60 9.6000 $15,215.27 0.1142 0.1166 $1,773.90

Total Facility Cost 2020 Net Plant Carrying Charge Monthly Wholesale Distribution Service Charge

$11,303.32 1.0600% $119.82

Wholesale Distribution Service Charge Support

Delivery Point Circuit Circuit Feet Circuit Circuit Cost Dollars Per Foot Eve Circuit SK7217 12-04 27,735 $5.8591 $162,502.14 Richards Circuit SK7217 12-04 61,027 $5.8591 $357,563.30

Delivery Point Metered Distribution Distribution Loss MW Loss Factor Adjusted MW Demand* Demand Eve 0.1142 1.0209 0.1166 Richards 0.0870 1.0209 0.0888

*Metered Demand at Peak 07/19/2019 05:00 PM

Attachment A

Reserved for future use.

ATTACHMENT B AGREEMENT FOR THE PROVISION OF

TRANSMISSION SERVICE TO MISSOURI BUNDLED RETAIL LOAD

This AGREEMENT FOR THE PROVISION OF TRANSMISSION SERVICE

TO MISSOURI BUNDLED RETAIL LOAD (hereinafter the “Agreement”) is entered into as of this ______day of ______2009, by and between Southwest Power Pool,

Inc. (“SPP”) and KCP&L Greater Missouri Operations Company (“KCP&L-GMO”).

This Agreement shall be supplemental to the Network Operating Agreement (“NOA”) and Service Agreement for Network Integration Transmission Service (“NITSA”) to be executed by KCP&L-GMO and SPP under SPP’s Open-Access Transmission Tariff

(“OATT”) on file with the Federal Energy Regulatory Commission (“FERC”). The transmission service provided by SPP pursuant to the terms and conditions of the NOA and NITSA and any successor transmission service shall hereinafter be referred to collectively as “Network Integration Transmission Service.” SPP and KCP&L-GMO are referred to, jointly, as the “Parties” and, individually, as a “Party.”

WITNESSETH:

WHEREAS, SPP is a FERC-approved Regional Transmission Organization

(“RTO”) with an open architecture that accommodates various forms of participation by transmission owning utilities; and

WHEREAS, KCP&L-GMO currently maintains open-access transmission tariffs approved by the FERC; and

WHEREAS, KCP&L-GMO currently provides and will continue to provide

Bundled Electric Service (including capacity, energy, transmission and distribution) to

Missouri Bundled Retail Load pursuant to rates established by the Missouri Public

Service Commission (“MoPSC”) and in accord with certain tariffs and rate schedules on file with the MoPSC; and

WHEREAS, upon KCP&L-GMO receiving all necessary regulatory approvals for continued participation in SPP, including the approval of the transfer of functional control of KCP&L-GMO’s transmission facilities pursuant to the Membership

Agreement referred to below, KCP&L-GMO plans to utilize Network Integration

Transmission Service from SPP, while this Agreement is in effect, in order to provide the transmission services necessary to furnish Bundled Electric Service to Missouri Bundled

Retail Load; and

1 WHEREAS, the FERC, in various orders and in its White Paper, Wholesale

Power Market Platform, issued April 28, 2003 (“White Paper”), contemplated, among other things, that a transmission owner and the RTO in which it holds membership may elect to enter into a service agreement that specifies that the wholesale rate for transmission service used to provide bundled retail electric service will be the transmission component of the bundled retail rates set by the state commission with retail jurisdiction over the transmission owner; and

WHEREAS, the Parties hereto desire to codify the specific terms and conditions stated herein under which SPP will provide Network Integration Transmission Service to

KCP&L-GMO to serve its Missouri Bundled Retail Load in addition to the terms and

1 Cleco Power, et al., 103 FERC ¶ 61,272 (2003), and Midwest Indep. Trans. System Operator, Inc., 102 FERC ¶ 61,192 (2003). conditions set forth in SPP’s NITSA and NOA except as otherwise stated in this

Agreement.

NOW, THEREFORE, in consideration of the premises and the mutual covenants and agreements herein contained, which each of the Parties hereto acknowledges to be sufficient consideration, SPP and KCP&L-GMO agree as follows:

ARTICLE I - DEFINITIONS

Terms not specifically defined in this Article or elsewhere in this Agreement have the same meaning as in the SPP OATT or the SPP Membership Agreement as these documents may be amended from time to time.

Section 1.1. Bundled Electric Service: The provision of electric service as a single service that includes all component services (capacity, energy, transmission and distribution) as distinguished from the provision of electric service where some or all such components are sold and purchased as separate (“unbundled”) services.

Section 1.2 Missouri Bundled Retail Load: The load of retail electric customers of KCP&L-GMO in the State of Missouri, on whose behalf and to whom

KCP&L-GMO, by statute, franchise, regulatory requirement or contract, has an obligation to provide Bundled Electric Service.

Section 1.3 SPP Membership Agreement: The Southwest Power Pool, Inc.

Membership Agreement (SPP’s Original Volume No. 3), as amended from time to time in accordance with its terms.

Section 1.4 SPP OATT: The open-access transmission tariff of SPP (SPP’s FERC

Electric Tariff, Fifth Revised Volume No. 1), as amended from time to time.

ARTICLE II - FILING, EFFECTIVE DATE, INITIAL TERM AND TERMINATION

Section 2.1 As soon as practicable following the execution of this Agreement,

SPP shall file this Agreement with the FERC for acceptance or approval. If the FERC accepts this Agreement without conditions or modifications, this Agreement shall become effective on the date upon which KCP&L-GMO exercises the authorization provided by the Missouri Public Service Commission in Case No. EO-2009-0179 (the

“Effective Date”). Each Party shall use its best efforts to gain prompt FERC acceptance or approval of this Agreement without modification or change, and agrees to provide support for this Agreement in public forums and elsewhere.

Section 2.2 If the FERC accepts this Agreement for filing, but subject to modification or change, and requires a compliance filing by either or both of the Parties, the Parties shall evaluate whether such required compliance filing materially changes or frustrates the intent of this Agreement. If either Party determines, in good faith, that the changes or modifications required by the FERC constitute a material change or may frustrate the intent of the Agreement, the Parties agree to negotiate in good faith to establish new terms and conditions that place the Parties in the same position as bargained for in this Agreement. If within thirty (30) days after the FERC’s conditional acceptance of the Agreement, or such other reasonable time period as may be mutually agreed to by the Parties, the Parties have not reached agreement on new terms and conditions or, if the amended Agreement is not subsequently unconditionally approved or accepted by the FERC, the Agreement shall be void, and neither Party shall have further obligations to the other Party hereunder.

Section 2.3 This Agreement shall remain in effect following the Effective Date for an initial term ending the earlier of: (i) the date that KCP&L-GMO withdraws from

SPP, or (ii) at 12:00:01 a.m., on October 1, 2013. Subject to the termination provisions of this Section 2.3, the Initial Term shall automatically be extended from year to year (a

“Renewal Term”) unless either Party shall have given the other six (6) months written notice of termination prior to the end of the Initial Term, or the end of any Renewal Term if such notice is given at least six (6) months prior to the end of that Renewal Term.

Section 2.4 Nothing in this Agreement shall in any way affect the rights or obligations of KCP&L-GMO with regard to withdrawal from SPP pursuant to the terms and conditions of the SPP Membership Agreement, Bylaws, and OATT, or any MoPSC order pertaining to KCP&L-GMO’s participation in SPP. Nor shall anything in this

Agreement affect in any way the rights or obligations of SPP to enforce or seek the enforcement of any terms in its Membership Agreement, Bylaws and OATT relating to any withdrawal by KCP&L-GMO.

ARTICLE III - RATE FOR TRANSMISSION SERVICE TO SERVE MISSOURI BUNDLED RETAIL LOAD

Section 3.1 Schedule 9 of the SPP OATT establishes a zonal transmission rate applicable to load within the KCP&L-GMO pricing zone that is taking Network

Integration Transmission Service from SPP. Notwithstanding Schedule 9 and the rates therein, KCP&L-GMO does not concede that the FERC has jurisdiction over the transmission component of Bundled Electric Service provided to Missouri Bundled Retail

Load using its own facilities, and does not voluntarily submit to such jurisdiction.

KCP&L-GMO shall not pay the rate set forth in Schedule 9 of the SPP OATT for using its own facilities to serve its Missouri Bundled Retail Load, but will include Missouri

Bundled Retail Load in the total load used to calculate the zonal rate for the KCP&L-

GMO zone. However, this provision shall not eliminate any obligation that KCP&L-

GMO may have to pay applicable charges related to facilities owned by other entities in

KCP&L-GMO’s zone that are unaffiliated with KCP&L-GMO.

Section 3.2 KCP&L-GMO, when taking transmission service from SPP in order to serve its Missouri Bundled Retail Load, shall not pay ancillary service charges pursuant to Schedules 3, 5 and 6 of the SPP OATT to the extent that KCP&L-GMO self- provides such ancillary services pursuant to the NITSA consistent with Part III of SPP’s

OATT. With regard to Schedules 1 and 2, KCP&L-GMO shall not be required to pay

SPP for the portion of those services for which it would receive the revenues from such services. If a portion of the revenues from Schedules 1 and 2 would be distributed to others, KCP&L-GMO shall be obligated to pay such portion to SPP.

Section 3.3 Except as otherwise provided in Sections 3.1 and 3.2, KCP&L-

GMO shall be subject to and shall pay to SPP all applicable SPP OATT charges associated with Network Integration Transmission Service taken by KCP&L-GMO to serve Missouri Bundled Retail Load. Such charges include, but are not limited to,

Attachments H, J, K, M, U, V, Z, AE, and AK and Schedules 1A, 4 (to the extent

Schedule 4 reflects the energy costs associated with SPP’s Energy Imbalance Services market), 11, and 12 of the SPP OATT.

Section 3.4 As a Network Integration Transmission Service customer of SPP serving its Missouri Bundled Retail Load, KCP&L-GMO shall be subject to all non-rate related terms and conditions under the SPP OATT applicable to Network Integration

Transmission Service.

ARTICLE IV - MISCELLANEOUS

Section 4.1 The obligations of the Parties shall be binding on and inure to the benefit of their respective successors and assigns.

Section 4.2 A written waiver of a right, remedy or obligation under a provision of this Agreement will not constitute a waiver of the provision itself, a waiver of any succeeding right, remedy or obligation under the provision, or waiver of any other right, remedy, or obligation under this Agreement. Any delay or failure by a Party in enforcing any obligation or in exercising any right or remedy shall not operate as a waiver of it or affect that Party’s right later to enforce the obligation or exercise the right or remedy, and a single or partial exercise of a right or remedy by a Party does not preclude any further exercise of it or the exercise of any other right or remedy of that Party.

Section 4.3 This Agreement may be executed in one or more counterparts, each of which shall be deemed an original, and all of which shall constitute one and the same instrument.

Section 4.4 Every notice, consent or approval required or permitted under this

Agreement shall be valid only if in writing, delivered personally or by mail, confirmed facsimile, or commercial courier, and sent by the sender to each other Party at its address or number below, or to such other address or number as each Party may designate by notice to the other Party. A validly given notice, consent or approval will be effective when received if delivered personally or by facsimile, or commercial courier, or certified mail with return receipt requested, postage prepaid.

If to KCP&L-GMO, to:

Vice President – Transmission Policy, Planning and Compliance 1201 Walnut, 21st Floor Kansas City, Missouri 64106 Fax No. (816) 556-2924

If to SPP, to:

President Southwest Power Pool, Inc. 415 North McKinley, Suite 140 Little Rock, Arkansas 72205-3020 Fax No. (501) 664-9553

Section 4.5 Upon the reasonable request of the other Party, each Party hereto agrees to take any and all such actions as are necessary or appropriate to give effect to the terms set forth in this Agreement and are not inconsistent with the terms hereof.

IN WITNESS WHEREOF, the Parties have caused this Agreement to be executed by their respective authorized officials.

KCP&L Greater Missouri Operations Company

By: /s/ Richard A. Spring Richard A. Spring Vice President – Transmission Policy, Planning and Compliance Southwest Power Pool, Inc.

By: /s/ Nick Brown Nicholas A. (Nick) Brown President and CEO

Non-Conforming Language in the Network Operating Agreement 13.0 Billing and Payments

Billing and Payments shall be in accordance with Attachment AE and Section 7 of the Tariff and the Agreement for the Provision of Transmission Service to Missouri Bundled Retail Load (“Missouri Agreement”), included as Attachment B to the Service Agreement.

17.0 Entire Agreement

The Tariff and Service Agreement, as they are amended from time to time, are incorporated herein and made a part hereof. To the extent that a conflict exists between the terms of this Operating Agreement and the terms of the Tariff, the Tariff shall control except with regard

to the provisions of the Missouri Agreement.

Southwest Power Pool, Inc. Twenty-Third Revised Service Agreement No. 1276

SERVICE AGREEMENT FOR NETWORK INTEGRATION TRANSMISSION SERVICE BETWEEN SOUTHWEST POWER POOL, INC. AND EVERGY METRO, INC.

This Network Integration Transmission Service Agreement ("Service Agreement") is entered into this 1st day of March, 2021, by and between Evergy Metro, Inc. ("Network Customer"), and Southwest Power Pool, Inc. ("Transmission Provider"). The Network Customer and Transmission Provider shall be referred to individually as “Party” and collectively as "Parties." WHEREAS, the Transmission Provider has determined that the Network Customer has made a valid request for Network Integration Transmission Service in accordance with the Transmission Provider’s Open Access Transmission Tariff ("Tariff") filed with the Federal Energy Regulatory Commission ("Commission") as it may from time to time be amended; WHEREAS, the Transmission Provider administers Network Integration Transmission Service for Transmission Owners within the SPP Region and acts as agent for the Transmission Owners in providing service under the Tariff; WHEREAS, the Network Customer has represented that it is an Eligible Customer under the Tariff; and WHEREAS, the Parties intend that capitalized terms used herein shall have the same meaning as in the Tariff. NOW, THEREFORE, in consideration of the mutual covenants and agreements herein, the Parties agree as follows:

1 NITS Application 1423

1.0 The Transmission Provider agrees during the term of this Service Agreement, as it may be amended from time to time, to provide Network Integration Transmission Service in accordance with the Tariff to enable delivery of power and energy from the Network Customer’s Network Resources that the Network Customer has committed to meet its load. 2.0 The Network Customer agrees to take and pay for Network Integration Transmission Service in accordance with the provisions of Parts I, III and V of the Tariff and this Service Agreement with attached Specifications and subject to the provisions of the Agreement for the Provision of Transmission Service to Missouri Bundled Retail Load (“Missouri Agreement”). 3.0 The terms and conditions of such Network Integration Transmission Service shall be governed by the Tariff, as in effect at the time this Service Agreement is executed by the Network Customer, or as the Tariff is thereafter amended or by its successor tariff, if any. The Tariff as it currently exists, or as it is hereafter amended is incorporated in this Service Agreement by reference. In the case of any conflict between this Service Agreement and the Tariff, the Tariff shall control except as provided in the Missouri Agreement. The Network Customer has been determined by the Transmission Provider to have a Completed Application for Network Integration Transmission Service under the Tariff. The completed specifications are based on the information provided in the Completed Application and are incorporated herein and made a part hereof as Attachment 1. 4.0 Service under this Service Agreement shall commence on such date as it is permitted to become effective by the Commission. This Service Agreement shall be effective through May 31, 2030. Upon termination, the Network Customer remains responsible for any outstanding charges including all costs incurred and apportioned or assigned to the Network Customer under this Service Agreement. 5.0 The Transmission Provider and Network Customer have executed a Network Operating Agreement as required by the Tariff.

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6.0 Any notice or request made to or by either Party regarding this Service Agreement shall be made to the representative of the other Party as indicated below. Such representative and address for notices or requests may be changed from time to time by notice by one Party or the other. Southwest Power Pool: Tessie Kentner Attorney 201 Worthen Dr. Little Rock, AR 72223-4936 Phone: (501) 688-1782 Email: [email protected] Network customer: Kevin Noblet Evergy Metro, Inc. Vice President - Safety and Operations Planning 1200 Main Street Kansas City, MO 64105 Phone: (816) 701-7811 Email: [email protected]

7.0 This Service Agreement shall not be assigned by either Party without the prior written consent of the other Party, which consent shall not be unreasonably withheld. However, either Party may, without the need for consent from the other, transfer or assign this Service Agreement to any person succeeding to all or substantially all of the assets of such Party. However, the assignee shall be bound by the terms and conditions of this Service Agreement. 8.0 Nothing contained herein shall be construed as affecting in any way the Transmission Provider’s or a Transmission Owner’s right to unilaterally make application to the Federal Energy Regulatory Commission, or other regulatory agency having jurisdiction, for any change in the Tariff or this Service Agreement under Section 205 of the Federal Power Act, or other applicable statute, and any rules and regulations promulgated

3 NITS Application 1423

thereunder; or the Network Customer's rights under the Federal Power Act and rules and regulations promulgated thereunder. 9.0 By signing below, the Network Customer verifies that all information submitted to the Transmission Provider to provide service under the Tariff is complete, valid and accurate, and the Transmission Provider may rely upon such information to fulfill its responsibilities under the Tariff. IN WITNESS WHEREOF, the Parties have caused this Service Agreement to be executed by their respective authorized officials.

TRANSMISSION PROVIDER NETWORK CUSTOMER

/s/ Lanny Nickell /s/ Kevin Noblet Signature Signature

Lanny Nickell Kevin Noblet Printed Name Printed Name

Vice President, Safety and Operations Planning, Evergy EVP & COO Metro, Inc. Title Title

3-11-2021 3-2-2021 Date Date

4 NITS Application 1423

ATTACHMENT 1 TO THE NETWORK INTEGRATION TRANSMISSION SERVICE AGREEMENT

BETWEEN SOUTHWEST POWER POOL, INC. AND EVERGY METRO, INC. SPECIFICATIONS FOR NETWORK INTEGRATION TRANSMISSION SERVICE

1.0 Network Resources The Network Resources are listed in Appendix 1. 2.0 Network Loads The Network Load consists of the bundled native load or its equivalent for Network Customer load in Kansas City Power & Light, Kansas City Power & Light Greater Missouri Operations Company, and Westar Zone(s) as listed in Appendix 3. The Network Customer’s Network Load shall be measured on an hourly integrated basis, by suitable metering equipment located at each connection and delivery point, and each generating facility. The meter owner shall cause to be provided to the Transmission Provider, Network Customer and applicable Transmission Owner, on a monthly basis such data as required by Transmission Provider for billing. The Network Customer’s load shall be adjusted, for settlement purposes, to include applicable Transmission Owner transmission and distribution losses, as applicable, as specified in Sections 8.5 and 8.6, respectively. For a Network Customer providing retail electric service pursuant to a state retail access program, profiled demand data, based upon revenue quality non-IDR meters may be substituted for hourly integrated demand data. Measurements taken and all metering equipment shall be in accordance with the Transmission Provider’s standards and practices for similarly determining the Transmission Provider’s load. The actual hourly Network Loads, by delivery point, internal generation site and point where power may flow to and from the Network Customer, with separate readings for each direction of flow, shall be provided. 3.0 Affected Zone(s) and Intervening Systems Providing Transmission Service The Zone(s) area are Kansas City Power & Light, Kansas City Power & Light Greater Missouri Operations Company, and Westar. The intervening system providing transmission service are none. 4.0 Electrical Location of Initial Sources See Appendix 1. 5.0 Electrical Location of the Ultimate Loads 5 NITS Application 1423

The loads of Network Customer identified in Section 2.0 hereof as the Network Load are electrically located within the Kansas City Power & Light, Kansas City Power & Light Greater Missouri Operations Company, and Westar Zone(s). 6.0 Delivery Points The delivery points are the interconnection points identified in Section 2.0 as the Network Load. 7.0 Receipt Points The Points of Receipt are listed in Appendix 2. 8.0 Compensation Service under this Service Agreement may be subject to some combination of the charges detailed below. The appropriate charges for individual transactions will be determined in accordance with the terms and conditions of the Tariff. 8.1 Transmission Charge Monthly Demand Charge per Section 34 and Part V of the Tariff shall be treated pursuant to the Missouri Agreement. 8.2 System Impact and/or Facility Study Charge Studies may be required in the future to assess the need for system reinforcements in light of the ten-year forecast data provided. Future charges, if required, shall be in accordance with Section 32 of the Tariff. 8.3 Direct Assignment Facilities Charge 8.4 Ancillary Service Charges 8.4.1 The following Ancillary Services are required under this Service Agreement. a) Scheduling System Control and Dispatch Service per Schedule 1 of the Tariff. b) Tariff Administration Service per Schedule 1-A1 of the Tariff. c) Reactive Supply and Voltage Control from Generation Sources Service per Schedule 2 of the Tariff. d) Regulation and Frequency Response Service per Schedule 3 of the Tariff. e) Energy Imbalance Service per Schedule 4 of the Tariff. f) Operating Reserve - Spinning Reserve Service per Schedule 5 of the Tariff. g) Operating Reserve - Supplemental Reserve Service per Schedule 6 of the Tariff.

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The Ancillary Services may be self-supplied by the Network Customer or provided by a third party in accordance with Sections 8.4.2 through 8.4.4, with the exception of the Ancillary Services for Schedules 1, 1-A, and 2, which must be purchased from the Transmission Provider. 8.4.2 In accordance with the Tariff, when the Network Customer elects to self-supply or have a third party provide Ancillary Services, the Network Customer shall indicate the source for its Ancillary Services to be in effect for the upcoming calendar year in its annual forecasts. If the Network Customer fails to include this information with its annual forecasts, Ancillary Services will be purchased from the Transmission Provider in accordance with the Tariff. 8.4.3 When the Network Customer elects to self-supply or have a third party provide Ancillary Services and is unable to provide its Ancillary Services, the Network Customer will pay the Transmission Provider for such services and associated penalties in accordance with the Tariff as a result of the failure of the Network Customer’s alternate sources for required Ancillary Services. 8.4.4 All costs for the Network Customer to supply its own Ancillary Services shall be the responsibility of the Network Customer. 8.5 Real Power Losses - Transmission The Network Customer shall be responsible for losses in accordance with Attachment M of the Tariff. 8.6 Real Power Losses – Distribution For Delivery Points on Evergy Kansas Central, Inc. Network System: The Network Customer shall replace all distribution losses in accordance with Evergy Kansas Central, Inc.'s Open Access Transmission Tariff, Section 28.5, based upon the location of each delivery point meter located on distribution facilities. The composite loss percentages in Section 28.5 shall exclude transmission losses. 8.7 Power Factor Correction Charge 8.8 Redispatch Charge Redispatch charges shall be in accordance with Section 33.3 of the Tariff. 8.9 Wholesale Distribution Service Charge

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For Delivery Points on Evergy Kansas Central, Inc. Network System: The Wholesale Distribution Service Charge cost support and monthly charge is detailed in Appendix 4. 8.10 Network Upgrade Charges A. Network Customer has confirmed the following supplemental Network Resources

requiring Network Upgrades.

1. Slate Creek Wind, 150 MW from POR – WR, Source – KCPLSLATECREEK to POD – KCPL, Sink KCPL_MPS, more specifically identified as TSR 80878929 studied in 2015-AG1 and now confirmed as 82196067 depends on and is contingent on completion of the following aggregate study SPP-2015-AG1 Service Upgrades, Expansion Plan Upgrades, and Planned Projects by the required date as listed below. Designation of this network resource shall be effective from March 1, 2016 to September 1, 2036. Network Customer is allocated monthly revenue requirements of $6423.55 from September 1, 2016 – March 1, 2036 over the 246 month term of this service. Total revenue requirement for the term is $1,580,193. Requested service depends on and is contingent on completion of the following Planned Projects. These upgrades costs are not assignable to the Network Customer. Planned Project

Upgrade Name Upgrade Description Transmission Owner Need Date SWISSVALE - Replace Terminal Equipment WERE 6/1/2021 WEST GARDNER 345KV CKT 1 WERE

2. Rock Creek Wind, 300 MW from POR – MPS, Source – KCPLROCKCREEK to POD – KCPL, Sink KCPL_MPS, more specifically identified as TSR 80887601 studied in 2015-AG1 and now confirmed as 82196071 depends on and is contingent on completion of the following aggregate study 2015-AG1 Planned Projects by the required date as listed below. Costs of these upgrades are not assigned to the Network Customer. Designation of this network resource shall be effective from December 31, 2016 to December 31, 2037.

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Planned Project

Upgrade Name Upgrade Description Transmission Owner Need Date SWISSVALE - Replace Terminal Equipment WERE 6/1/2021 WEST GARDNER 345KV CKT 1 WERE

3. Osborn Wind, 200 MW from POR – MPS, Source – OSBORN to POD – KCPL, Sink KCPL_MPS, more specifically identified as TSR 80888058 studied in 2015- AG1 and now confirmed as 82196085 depends on and is contingent on completion of the following aggregate study 2015-AG1 Planned Projects by the required date as listed below. Costs of these upgrades are not assigned to the Network Customer. Designation of this network resource shall be effective from December 31, 2016 to December 31, 2037.

Planned Project

Upgrade Name Upgrade Description Transmission Owner Need Date SWISSVALE - Replace Terminal Equipment WERE 6/1/2021 WEST GARDNER 345KV CKT 1 WERE

4. Spearville Wind, 50 MW from POR – WPEK, Source – SPEARVILLE to POD – KCPL, Sink KCPL_MPS, more specifically identified as TSR 81620079 studied in 2015-AG2 depends on and is contingent on completion of the following Construction Pending and Planned Projects by the required date as listed below. Costs of these upgrades are not assigned to the Network Customer. Designation of this network resource shall be effective from January 1, 2017 to January 1, 2022.

Planned Project

Upgrade Name Upgrade Description Transmission Owner Need Date SWISSVALE - Replace terminal equipment. WERE 6/1/2017 WEST GARDNER 345KV CKT 1 WERE

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5. Spearville Wind, 50 MW from POR – WPEK, Source – SPEARVILLE to POD – KCPL, Sink KCPL_MPS, more specifically identified as TSR 81921840 studied in 2015-AG2 depends on and is contingent on completion of the following Construction Pending and Planned Projects by the required date as listed below. Costs of these upgrades are not assigned to the Network Customer. Designation of this network resource shall be effective from January 1, 2017 to January 1, 2022.

Planned Project

Upgrade Name Upgrade Description Transmission Owner Need Date SWISSVALE - Replace terminal equipment. WERE 6/1/2017 WEST GARDNER 345KV CKT 1 WERE

6. For Jeffrey Energy Center 2 Purchase, more specifically studied in 2017-AG1 as 84885455 and confirmed as 84885455, service is contingent upon completion of the Potential System Constraints Projects identified in 2017-AG1. Designation of this resource shall be effective on December 1, 2017 and shall remain effective through June 1, 2030. Costs of this project are not assigned to the Network Customer.

Potential System Constraints Projects

Upgrade Name Upgrade Description Transmission Date Required in Owner Service LEXINGTON 161/69KV Replace Lexington Evergy 10/1/2019 TRANSFORMER CKT 1 161/69 kV transformer Metro, Inc. (71987) with 100/110 MVA transformer. MIDLANDS3 115.00 - Replace limiting 750 CU WERE 6/1/2022 MIDLAND JUNCTION 115KV Bus (201/240 MVA) CKT Z1 with 1590 AAC Bus (71998) (255/308 MVA).

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C. Notwithstanding the term provisions of Section 4.0 of this Service Agreement, Customer shall be responsible for paying all charges specified as its obligation in this Section 8.9 of this Attachment 1, for the term specified herein for each assigned upgrade. 8.11 Meter Data Processing Charge 8.12 Other Charges A. Network Customer has confirmed the following supplemental Network Resources requiring payment of revenue credits to Upgrade Sponsors of the following Creditable Upgrades in accordance with Attachment Z2 of the SPP OATT. Transmission Customers will only receive charges and/or credits for the Upgrades with a “Directly Assigned” amount in the table in Section 8.12.

Upgrade Total Credit Amount Amount of Studied Start Date End Date Name Payment Due Covered By Service Directly Base Plan Request# Funding Assigned LACYGNE - $203,208.00 $203,208.00 $- 1223092 6/1/2011 6/1/2031 WEST GARDNER 345KV CKT 1 Valliant 345 $181,884.00 $181,884.00 $- 1223092 6/1/2011 6/1/2031 kV (AEP) HUGO - $1,077,242.40 $1,077,242.40 $- 1223092 6/1/2011 6/1/2031 VALLIANT 345KV CKT 1 LACYGNE - $203,208.00 $203,208.00 $- 1223093 6/1/2011 6/1/2031 WEST GARDNER 345KV CKT 1 Valliant 345 $181,884.00 $181,884.00 $- 1223093 6/1/2011 6/1/2031 kV (AEP) HUGO - $1,077,242.40 $1,077,242.40 $- 1223093 6/1/2011 6/1/2031 VALLIANT 345KV CKT 1 LACYGNE - $203,208.00 $203,208.00 $- 1223094 6/1/2011 6/1/2031 WEST GARDNER 345KV CKT 1 11 NITS Application 1423

Upgrade Total Credit Amount Amount of Studied Start Date End Date Name Payment Due Covered By Service Directly Base Plan Request# Funding Assigned Valliant 345 $181,884.00 $181,884.00 $- 1223094 6/1/2011 6/1/2031 kV (AEP) HUGO - $1,077,242.40 $1,077,242.40 $- 1223094 6/1/2011 6/1/2031 VALLIANT 345KV CKT 1 LACYGNE - $203,208.00 $203,208.00 $- 1223095 6/1/2011 6/1/2031 WEST GARDNER 345KV CKT 1 Valliant 345 $181,884.00 $181,884.00 $- 1223095 6/1/2011 6/1/2031 kV (AEP) HUGO - $1,077,242.40 $1,077,242.40 $- 1223095 6/1/2011 6/1/2031 VALLIANT 345KV CKT 1 LACYGNE - $252,095.76 $252,095.76 $- 1405741 5/1/2011 5/1/2025 WEST GARDNER 345KV CKT 1 LACYGNE - $40,336.80 $40,336.80 $- 75181547 1/1/2014 1/1/2024 WEST GARDNER 345KV CKT 1 NORTHWES $187,172.40 $187,172.40 $- 75181547 1/1/2014 1/1/2024 T - WOODWAR D 345KV CKT 1 LACYGNE - $39,702.00 $39,702.00 $- 75181564 1/1/2014 1/1/2024 WEST GARDNER 345KV CKT 1 NORTHWES $178,176.00 $178,176.00 $- 75181564 1/1/2014 1/1/2024 T - WOODWAR D 345KV CKT 1

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Upgrade Total Credit Amount Amount of Studied Start Date End Date Name Payment Due Covered By Service Directly Base Plan Request# Funding Assigned LACYGNE - $43,591.20 $43,591.20 $- 75181568 1/1/2014 1/1/2024 WEST GARDNER 345KV CKT 1 NORTHWES $194,931.60 $194,931.60 $- 75181568 1/1/2014 1/1/2024 T - WOODWAR D 345KV CKT 1 LACYGNE - $127,564.88 $127,564.88 $- 76216053 2/1/2014 4/1/2032 WEST GARDNER 345KV CKT 1 NORTHWES $991,849.86 $664,540.30 $327,309.56 76216053 2/1/2014 4/1/2032 T - WOODWAR D 345KV CKT 1 FLATRDG3 - $183,745.66 $123,108.96 $60,636.70 76216053 2/1/2014 4/1/2032 HARPER 138KV CKT 1 MEDICINE $3,559.94 $2,384.92 $1,175.02 76216053 2/1/2014 4/1/2032 LODGE - PRATT 115KV CKT 1 Buckner $4,701,839.26 $4,701,839.26 $- 76216053 2/1/2014 4/1/2032 345kV Substation Buckner $158,595.00 $158,595.00 $- 76216053 2/1/2014 4/1/2032 345kV Substation GEN-2010- 009 Addition LACYGNE - $195,099.10 $195,099.10 $- 76216066 2/1/2014 4/1/2032 WEST GARDNER 345KV CKT 1

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Upgrade Total Credit Amount Amount of Studied Start Date End Date Name Payment Due Covered By Service Directly Base Plan Request# Funding Assigned NORTHWES $1,318,658.02 $883,501.68 $435,156.34 76216066 2/1/2014 4/1/2032 T - WOODWAR D 345KV CKT 1 FLATRDG3 - $370,347.12 $248,131.96 $122,215.16 76216066 2/1/2014 4/1/2032 HARPER 138KV CKT 1 MEDICINE $5,711.60 $3,825.90 $1,885.70 76216066 2/1/2014 4/1/2032 LODGE - PRATT 115KV CKT 1 LACYGNE - $1,036,958.88 $1,036,958.88 $- 79385758 10/1/2015 4/1/2036 WEST GARDNER 345KV CKT 1 Tap on Wolf $17,625,732.72 $17,625,732.72 $- 79385758 10/1/2015 4/1/2036 Creek - LaCygne 345kV Ckt 1 Tap on Wolf $289,561.68 $289,561.68 $- 79385758 10/1/2015 4/1/2036 Creek - LaCygne 345kV Ckt 1 GEN-2010- 003 Addition LACYGNE - $523,613.46 $523,613.46 $- 79385763 10/1/2015 4/1/2036 WEST GARDNER 345KV CKT 1 Tap on Wolf $4,517,140.56 $4,517,140.56 $- 79385763 10/1/2015 4/1/2036 Creek - LaCygne 345kV Ckt 1 Tap on Wolf $292,430.04 $292,430.04 $- 79385763 10/1/2015 4/1/2036 Creek - LaCygne 345kV Ckt 1 GEN-2010- 003 Addition

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Upgrade Total Credit Amount Amount of Studied Start Date End Date Name Payment Due Covered By Service Directly Base Plan Request# Funding Assigned LACYGNE - $513,345.42 $513,345.42 $- 79385767 10/1/2015 4/1/2036 WEST GARDNER 345KV CKT 1 Tap on Wolf $4,428,570.72 $4,428,570.72 $- 79385767 10/1/2015 4/1/2036 Creek - LaCygne 345kV Ckt 1 Tap on Wolf $286,695.78 $286,695.78 $- 79385767 10/1/2015 4/1/2036 Creek - LaCygne 345kV Ckt 1 GEN-2010- 003 Addition LACYGNE - $863,841.30 $863,841.30 $- 80878929 3/1/2016 9/1/2036 WEST GARDNER 345KV CKT 1 Shidler 138 $197,225.58 $132,141.36 $65,084.22 80878929 3/1/2016 9/1/2036 kV Osage - $16,309.80 $10,927.32 $5,382.48 80878929 3/1/2016 9/1/2036 Shidler 138kV Cresswell $1,522,056.12 $1,522,056.12 $- 80878929 3/1/2016 9/1/2036 138kV Substation GEN-2011- 057 Addition LACYGNE - $654,486.84 $- $654,486.84 80887601 12/31/2016 12/31/2037 WEST GARDNER 345KV CKT 1 Sub - Tap $2,608,401.60 $- $2,608,401.60 80887601 12/31/2016 12/31/2037 Nebraska City - Mullin Creek 345kV (Holt County) POI for GEN- 2014-021 (TSMO NU)

15 NITS Application 1423

Upgrade Total Credit Amount Amount of Studied Start Date End Date Name Payment Due Covered By Service Directly Base Plan Request# Funding Assigned Tap Nebraska $175,203.00 $- $175,203.00 80887601 12/31/2016 12/31/2037 City - Mullin Creek 345 kV (Holt County) POI for GEN- 2014-021 (OPPD NU) Sub - Tap $23,489,789.40 $- $23,489,789.40 80887601 12/31/2016 12/31/2037 Nebraska City - Mullin Creek 345kV (Holt County) POI for GEN- 2014-021 (SANU) LACYGNE - $407,622.60 $- $407,622.60 80888058 12/31/2016 12/31/2037 WEST GARDNER 345KV CKT 1 Ketchem $12,293,290.80 $- $12,293,290.80 80888058 12/31/2016 12/31/2037 345kV Interconnecti on Switching Station GEN- 2015-005 Addition (NU) LACYGNE - $96,802.80 $- $96,802.80 81620079 1/1/2017 1/1/2022 WEST GARDNER 345KV CKT 1 NORTHWES $626,838.00 $- $626,838.00 81620079 1/1/2017 1/1/2022 T - WOODWAR D 345KV CKT 1 Woodward $46,987.80 $- $46,987.80 81620079 1/1/2017 1/1/2022 EHV 138kV Phase Shifting Transformer circuit #1

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Upgrade Total Credit Amount Amount of Studied Start Date End Date Name Payment Due Covered By Service Directly Base Plan Request# Funding Assigned LACYGNE - $96,802.80 $- $96,802.80 81921840 1/1/2017 1/1/2022 WEST GARDNER 345KV CKT 1 NORTHWES $626,838.00 $- $626,838.00 81921840 1/1/2017 1/1/2022 T - WOODWAR D 345KV CKT 1 Woodward $46,987.80 $- $46,987.80 81921840 1/1/2017 1/1/2022 EHV 138kV Phase Shifting Transformer circuit #1 166TH $3,237.00 $3,237.00 $- 84885455 12/1/2017 6/1/2030 STREET - JAGGARD JUNCTION 115KV CKT 1 166TH $3,864.00 $3,864.00 $- 84885455 12/1/2017 6/1/2030 STREET - JARBALO JUNCTION SWITCHING STATION 115KV CKT 1 JAGGARD $6,499.50 $6,499.50 $- 84885455 12/1/2017 6/1/2030 JUNCTION - PENTAGON 115KV CKT 1 GEN-2015- $465.00 $465.00 $- 84885455 12/1/2017 6/1/2030 063 Tap - Mathewson 345kV CKT 1 LACYGNE - $2,229.00 $2,229.00 $- 84885455 12/1/2017 6/1/2030 WEST GARDNER 345KV CKT 1

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Upgrade Total Credit Amount Amount of Studied Start Date End Date Name Payment Due Covered By Service Directly Base Plan Request# Funding Assigned NORTHWES $603.00 $603.00 $- 84885455 12/1/2017 6/1/2030 T - WOODWAR D 345KV CKT 1 LACYGNE - $328,945.65 $- $328,945.65 85952034 9/1/2018 6/1/2032 WEST GARDNER 345KV CKT 1 NORTHWES $1,517,044.65 $- $1,517,044.65 85952034 9/1/2018 6/1/2032 T - WOODWAR D 345KV CKT 1 POWER $999.90 $999.90 $- 85952034 9/1/2018 6/1/2032 SYSTEM STABILIZE RS IN SPS Woodward $109,791.00 $- $109,791.00 85952034 9/1/2018 6/1/2032 EHV 138kV Phase Shifting Transformer circuit #1 FLATRDG3 - $187,934.58 $- $187,934.58 85955794 6/1/2018 12/1/2031 HARPER 138KV CKT 1 Ft. Dodge - $382,909.68 $- $382,909.68 85955794 6/1/2018 12/1/2031 North Ft. Dodge 115 kV Ckt 2 LACYGNE - $151,983.54 $- $151,983.54 85955794 6/1/2018 12/1/2031 WEST GARDNER 345KV CKT 1 MEDICINE $10,679.04 $- $10,679.04 85955794 6/1/2018 12/1/2031 LODGE - PRATT 115KV CKT 1

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Upgrade Total Credit Amount Amount of Studied Start Date End Date Name Payment Due Covered By Service Directly Base Plan Request# Funding Assigned MEDICINE $95,652.90 $- $95,652.90 85955794 6/1/2018 12/1/2031 LODGE 138/115KV TRANSFOR MER CKT 1 North Ft. $828,620.28 $- $828,620.28 85955794 6/1/2018 12/1/2031 Dodge - Spearville 115kV Ckt 2 NORTHWES $746,173.62 $- $746,173.62 85955794 6/1/2018 12/1/2031 T - WOODWAR D 345KV CKT 1 Spearville $1,378,386.72 $- $1,378,386.72 85955794 6/1/2018 12/1/2031 345/115 kV Transformer CKT 1 Woodward $53,497.26 $- $53,497.26 85955794 6/1/2018 12/1/2031 EHV 138kV Phase Shifting Transformer circuit #1 LACYGNE - $905,120.65 $- $905,120.65 85956901 1/1/2019 6/1/2039 WEST GARDNER 345KV CKT 1 Tap $12,059,235.65 $- $12,059,235.65 85956901 1/1/2019 6/1/2039 Centerville- Marmaton 161kV GEN- 2015-016 Addition (NU) Tap $166,271.70 $- $166,271.70 85956901 1/1/2019 6/1/2039 Centerville- Marmaton 161kV GEN- 2015-016 Addition (WERE)

19 NITS Application 1423

Upgrade Total Credit Amount Amount of Studied Start Date End Date Name Payment Due Covered By Service Directly Base Plan Request# Funding Assigned GEN-2015- $109,828.50 $- $109,828.50 85956933 1/1/2019 6/1/2049 063 Tap - Mathewson 345kV CKT 1 LACYGNE - $1,552,213.60 $- $1,552,213.60 85956933 1/1/2019 6/1/2049 WEST GARDNER 345KV CKT 1 NORTHWES $2,860,052.40 $- $2,860,052.40 85956933 1/1/2019 6/1/2049 T - WOODWAR D 345KV CKT 1 Tap Wichita - $11,174,507.85 $- $11,174,507.85 85956933 1/1/2019 6/1/2049 Thistle 345 kV Ckt 1 & 2 - GEN-2015- 024 Addition (NU) Tap Wichita - $13,457.55 $13,457.55 $- 85956933 1/1/2019 6/1/2049 Thistle 345 kV Ckt 1 & 2 - GEN-2015- 025 Addition (NU) Woodward $160,209.45 $- $160,209.45 85956933 1/1/2019 6/1/2049 EHV 138kV Phase Shifting Transformer circuit #1

B. Upon completion of construction of the assigned upgrades, funding of their costs shall be reconciled and trued-up against actual construction costs and requisite, additional funding or refund of excess funding shall be made between the Transmission Provider and the Network Customer. C. Notwithstanding the term provisions of Section 4.0 of this Service Agreement, Customer shall be responsible for paying all charges specified as its obligation in this

20 NITS Application 1423

Section 8.12 of this Attachment 1, for the term specified herein for each assigned upgrade. 8.13 Candidate Incremental LTCRs * Source ______* Sink ______* Candidate Incremental LTCR MW ______* Term (years from in-service date of Network Upgrade) ______9.0 Credit for Network Customer-Owned Transmission Facilities 10.0 Designation of Parties Subject to Reciprocal Service Obligation 11.0 Other Terms and Conditions

21 NITS Application 1423

APPENDIX 1

Network Resources of Evergy Metro, Inc.

22 NITS Application 1423

APPENDIX 1 EVERGY METRO, INC. NETWORK RESOURCES

Firm Network Resource Service Start Service Transmission Comments Name Date End Date Rights 75 MW capacity rights to CROSSROADS 1 8/1/2015 6/1/2030 75 MW 6/1/2032 75 MW capacity rights to CROSSROADS 2 8/1/2015 6/1/2030 75 MW 6/1/2032 75 MW capacity rights to CROSSROADS 3 8/1/2015 6/1/2030 75 MW 6/1/2032 75 MW capacity rights to CROSSROADS 4 8/1/2015 6/1/2030 75 MW 6/1/2032 GREENWOOD 1 8/1/2015 6/1/2030 63 MW GREENWOOD 2 8/1/2015 6/1/2030 61 MW GREENWOOD 3 8/1/2015 6/1/2030 66 MW GREENWOOD 4 8/1/2015 6/1/2030 63 MW HAWTHORN 5 8/1/2015 6/1/2030 563 MW HAWTHORN 6 8/1/2015 6/1/2030 162 MW HAWTHORN 7 8/1/2015 6/1/2030 90 MW HAWTHORN 8 8/1/2015 6/1/2030 90 MW HAWTHORN 9 8/1/2015 6/1/2030 130 MW IATAN 1_KCPL 8/1/2015 6/1/2030 501 MW IATAN 1_MPS 8/1/2015 6/1/2030 127 MW IATAN 2_MPS 8/1/2015 6/1/2030 162 MW IATAN 2_KCPL 8/1/2015 6/1/2030 500 MW JEFFREY EC 1 8/1/2015 6/1/2030 58 MW JEFFREY EC 2 12/1/2017 6/1/2030 59 MW JEFFREY EC 3 8/1/2015 6/1/2030 58 MW LACYGNE 1 8/1/2015 6/1/2030 370 MW LACYGNE 2 8/1/2015 6/1/2030 341 MW LAKE RD 1 8/1/2015 6/1/2030 22 MW LAKE RD 2 8/1/2015 6/1/2030 27 MW LAKE RD 3 8/1/2015 6/1/2030 11 MW LAKE RD 4 8/1/2015 6/1/2030 99 MW LAKE RD CT 5 8/1/2015 6/1/2030 62 MW LAKE RD JE 6 8/1/2015 6/1/2030 21 MW LAKE RD JE 7 8/1/2015 6/1/2030 22 MW NEVADA 8/1/2015 6/1/2030 21 MW NORTHEAST 11 8/1/2015 6/1/2030 63 MW NORTHEAST 12 8/1/2015 6/1/2030 63 MW NORTHEAST 13 8/1/2015 6/1/2030 65 MW NORTHEAST 14 8/1/2015 6/1/2030 65 MW NORTHEAST 15 8/1/2015 6/1/2030 65 MW 23 NITS Application 1423

NORTHEAST 16 8/1/2015 6/1/2030 65 MW NORTHEAST 17 8/1/2015 6/1/2030 65 MW NORTHEAST 18 8/1/2015 6/1/2030 65 MW NORTHEAST BLACK START 8/1/2015 6/1/2030 2 MW GENERATOR OSAWATOMIE CT 1 8/1/2015 6/1/2030 90 MW RALPH GREEN 3 8/1/2015 6/1/2030 72 MW SOUTH HARPER 1 8/1/2015 6/1/2030 105 MW SOUTH HARPER 2 8/1/2015 6/1/2030 106 MW SOUTH HARPER 3 8/1/2015 6/1/2030 104 MW 1/23/2020 6/1/2021 0 MW TWA 1 6/1/2021 6/1/2030 17 MW 1/24/2020 6/1/2022 0 MW TWA 2 6/1/2022 6/1/2030 17 MW WEST GARDNER CT 1 8/1/2015 6/1/2030 90 MW WEST GARDNER CT 2 8/1/2015 6/1/2030 90 MW WEST GARDNER CT 3 8/1/2015 6/1/2030 90 MW WEST GARDNER CT 4 8/1/2015 6/1/2030 90 MW WOLF CREEK 8/1/2015 6/1/2030 568 MW 200 MW capacity rights WAVERLY WIND 10/1/2015 6/1/2030 200 MW until 4/1/2036 NPPD JEFFREY 1 PURCHASE 8/1/2015 1/1/2025 20 MW NPPD JOHNSON 1 PURCHASE 8/1/2015 1/1/2025 20 MW NPPD JOHNSON 2 PURCHASE 8/1/2015 1/1/2025 22 MW WESTAR POWER PURCHASE 8/1/2015 6/1/2030 1 MW 132 MW capacity rights 132 MW until 6/1/2032 CIMARRON WIND PURCHASE 9/1/2018 6/1/2030 32 MW capacity rights 6/1/2032 to 4/1/2033 100 MW capacity rights ENSIGN WIND 8/1/2015 6/1/2030 100 MW until 4/1/2033 110 MW capacity rights GRAY COUNTY WIND 10/1/2019 6/1/2030 110 MW until 12/1/2031 SPEARVILLE WIND 50 MW capacity rights 8/1/2015 6/1/2030 50 MW PURCHASE 1 until 4/1/2033 SPEARVILLE WIND 8/1/2015 6/1/2030 101 MW PURCHASE 2 SPEARVILLE WIND 1/1/2017 6/1/2030 50 MW PURCHASE 3 SPEARVILLE WIND 1/1/2017 6/1/2030 50 MW PURCHASE 4 SLATE CREEK WIND 150 MW capacity rights 3/1/2016 6/1/2030 150 MW PURCHASE until 9/1/2036 ROCK CREEK WIND 300 MW capacity rights 1/1/2017 6/1/2030 300 MW PURCHASE until 1/1/2038 OSBORN WIND PURCHASE 1/1/2017 6/1/2030 200 MW 200 MW capacity rights 24 NITS Application 1423

until 1/1/2038 200 MW capacity rights PRAIRIE QUEEN WIND 4/1/2019 6/1/2030 200 MW until 6/1/2039 245 MW capacity rights PRATT WIND 1/1/2019 6/1/2030 245 MW until 6/1/2049

25 NITS Application 1423

Appendix 2

Receipt Points of Evergy Metro, Inc.

26 NITS Application 1423

APPENDIX 2 EVERGY METRO, INC. RECEIPT POINTS

Tieline / Plant Name Ownership Voltage (kV) Hawthorn EVERGY METRO, INC. 161 Iatan EVERGY METRO, INC. 345 LaCygne EVERGY METRO, INC. 345 Montrose EVERGY METRO, INC. 161 Northeast EVERGY METRO, INC. 161 Osawatomie EVERGY METRO, INC. 161 West Gardner EVERGY METRO, INC. 161 Wolf Creek #1 WERE 345 Spearville EVERGY METRO, INC. 230 Montrose-Clinton EVERGY METRO, INC. 161 Sibley 1 MIPU 69 Sibley 2 MIPU 69 Sibley 3 MIPU 161 Jeffrey EC 1 WERE 230 Jeffrey EC 2 WERE 345 Jeffrey EC 3 WERE 345 South Harper 1 MIPU 161 South Harper 2 MIPU 161 South Harper 3 MIPU 161 Ralph Green 3 MIPU 161 Greenwood 1 MIPU 161 Greenwood 2 MIPU 161 Greenwood 3 MIPU 161 Greenwood 4 MIPU 161 Nevada MIPU 69 TWA 1 MIPU 161 TWA 2 MIPU 161 Iatan #1 EVERGY METRO, INC. 345 Iatan #2 EVERGY METRO, INC. 345 Lake Rd #4 MIPU 161 Lake Rd #1 MIPU 34.5 Lake Rd #2 MIPU 34.5 Lake Rd #3 MIPU 34.5 Lake Rd CT MIPU 34.5 Lake Rd JE (6) MIPU 34.5 Lake Rd JE (7) MIPU 34.5 Gray County Wind Farm - (MPS) SECI/WPEK 115 Gray County Wind Farm - (SJLP) SECI/WPEK 115 Cooper-Fairport-St. Joseph MINT Line Members 345 Cooper-Fairport-St. Joseph MINT Line Members 345 Cooper-Fairport-St. Joseph MINT Line Members 345 Westar Evergy Kansas Central, Inc. 69 Slate Creek Wind Evergy Kansas Central, Inc. 138 Rock Creek Wind Evergy Missouri West, Inc. 345 Osborn Wind Evergy Missouri West, Inc. 138

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Appendix 3

Delivery Points of Evergy Metro, Inc.

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Appendix 3 Delivery Points

Delivery Point Name Ownership Voltage (kV)

Delivery Points in KCPL Zone Grand Av. West (15W) KACP 161/13 Grand Av. (15) KACP 161/13 Navy (17) KACP 161/13 Crosstown (24) KACP 161/13 Terrace (37) KACP 161/13 Chouteau (44) KACP 161/13 Blue Valley (53) KACP 161/13 Northeast (74) KACP 161/13 Hawthorn (96) KACP 161/13 Courtney (57) KACP 69/12 Blue Mills (79) KACP 69/12 Blue Springs (86) KACP 69/12 Sugar Creek (89) KACP 69/4 Duncan (118) KACP 69/12 Olin - Lake City KACP 69/ Mo. Water - Independence KACP 69/ Lafarge KACP 69/ Stilwell (16) KACP 161/12 Riley (19) KACP 161/12 Switzer (22) KACP 161/12 Oxford (38) KACP 161/12 Olathe (41) KACP 161/12 Antioch (65) KACP 161/12 Murlen (82) KACP 161/12 Redel (115) KACP 161/12 Sprint (119) KACP 161/- Lackman (114) KACP 161/12 Bonita - Westar (130) Evergy Kansas 161/12 Central, Inc. South Ottawa (46) KACP( includes 161/34 KMEA NITS load to City of Ottawa) Paola (55) KACP (includes 161/34 KMEA NITS load to City of Osawatomie) Centennial (73) KACP 161/12 W Gardner (81) KACP(includes 161/34 KMEA NITS load to City of Baldwin) Centerville (108) KACP (includes 161/34 KMEA NITS load to City of Garnett) Wagstaff (113) KACP 161/34 Bucyrus (117) KACP 161/12 N. Louisburg (121) KACP 161/12 29 NITS Application 1423

Delivery Point Name Ownership Voltage (kV)

Pleasant Valley (137) KACP 161/34 MiddleCreek (135) KACP 161/12 Twilight (133) not in models KACP 161/12 Cedar Niles (132) KACP 161/12 Hillsdale (134) KACP 161/12 K68 & Block Rd KACP 161/12 K68 & Lonestar KACP 161/12 Spring Hill-Westar Evergy Kansas 115/12 Central, Inc. Southtown (23) KACP 161/13 Swope (30) KACP 161/12 Forest (31) KACP 161/13 Loma Vista (35) KACP 161/12 Tomahawk (48) KACP 161/12 Hickman (56) KACP 161/12 Leeds (61) KACP 161/13 Martin City (66) KACP 161/12 Midtown (75) KACP 161/13 Bunker Ridge (84) KACP 161/13 Allied Signal (CO 1319) KACP 161/13 Birmingham (10) KACP 161/12 Barry (11) KACP 161/12 Avondale (27) KACP 161/12 Tiffany Springs (39) KACP 161/12 Weatherby (49) KACP 161/12 Claycomo (52) KACP 161/12 Line Creek (63) KACP 161/12 Shoal Creek (70) KACP 161/12 Randolph (71) KACP 161/12 Gladstone (78) KACP 161/12 NKC (94) KACP 161/13 Riverside (98) KACP 161/12 Waldron (111) KACP 161/12 Brookridge (12) KACP 161/12 Shawnee (13) KACP 161/12 Reeder (20) KACP 161/12 Lenexa(29) - North (3,4,6) KACP 161/12 Lenexa- South (2) KACP 161/12 Lacygne KACP 345/69 Overland Park (47) KACP 161/12 Keniworth (50) KACP 161/12 Cedar Creek (51) KACP 161/12 Roeland Park (68) KACP 161/12 Moonlight (69) KACP (KMEA NITS 161/12 load to City of Gardner via bus 58056) College (90) KACP 161/12 Merriam (91) KACP 161/12 30 NITS Application 1423

Delivery Point Name Ownership Voltage (kV)

Greenwood (93) KACP 161/12 Pflumn (125) KACP 161/12 Quarry (128) KACP 161/12 Sunflower KACP 161/12 City of Marshall (PO 2212) KACP 161/- Brunswick (42) KACP 161/34 Salisbury (83) KACP 161/34 Norton (95) KACP 161/34 Carrollton (104) KACP 161/34 Corder (34) KACP 69/12 Higginsville (110) KACP 69/12 W Higginsville (120) KACP 69/12 City of Higginsville (PO2259) KACP 69/12 AEC Dover (PO2116) KACP 69/12 AMOCO (COL1607) KACP 69/12 AEC Higginsville KACP 69/12 S Waverly #2 (127) KACP 161/34 Malta Bend (136) KACP 161/12 Plumrrd KACP 69/12 Charlot KACP 161/12

Delivery Points in KCPL GMO Zone TWA#1 MIPU 13 TWA#2 MIPU 13 LAKERD3 MIPU 34.5 SMTHVL MIPU 161 BLSPE 5 MIPU 161 PRALEE MIPU 161 SEDALIA MIPU 161 BLSPS 5 MIPU 161 KCI 5 MIPU 161 FRLVW 5 MIPU 161 HLLMRK MIPU 161 WINDSR MIPU 161 RAYTOWN MIPU 161 FROSTRD MIPU 161 PLTCTY MIPU 161 WSTELEC MIPU 161 GRDVWE MIPU 161 LNGVW 5 MIPU 161 GRAINVL MIPU 161 OAKGRV MIPU 161 WBURGE MIPU 161 LEESUM MIPU 161 WAFB 5 MIPU 161 DUNCAN MIPU 161 RICHMND MIPU 161 BLSPW 5 MIPU 161 LKWOOD MIPU 161 31 NITS Application 1423

Delivery Point Name Ownership Voltage (kV)

ADRIAN MIPU 161 SEDEAST MIPU 161 LKWINGB MIPU 161 ORRICK MIPU 161 KCSOUTH MIPU 161 STROTHR MIPU 161 LBRTYWT MIPU 161 LBRTYST MIPU 161 HOOKRD MIPU 161 MARYVLE MIPU 161 EAST 5 MIPU 161 IND PRK MIPU 161 COOK 5 MIPU 161 WOODBIN MIPU 161 TURNER MIPU 161 STALEY MIPU 69 LIBERTY MIPU 69 SIBLEY MIPU 69 LEXNTON MIPU 69 13&40 2 MIPU 69 WBURGP MIPU 69 WBURGE MIPU 69 KNOSTER MIPU 69 KELHYS MIPU 69 PITTCRN MIPU 69 SEDPLT MIPU 69 COLECMP MIPU 69 WARSAW MIPU 69 HOLDEN MIPU 69 RGREEN MIPU 69 BRMALL MIPU 69 GRDWCTY MIPU 69 GRDWST MIPU 69 RGAFB 2 MIPU 69 BELTON MIPU 69 BELTONS MIPU 69 FREEMAN MIPU 69 ANCONDA MIPU 69 HSNVLW MIPU 69 GRDNCTY MIPU 69 GUNNPS2 MIPU 69 POSTOAK MIPU 69 CLNTPLT MIPU 69 CLNTGRN MIPU 69 URICH 2 MIPU 69 APCITY MIPU 69 NEVPLT MIPU 69 METZ 2 MIPU 69 3M 2 MIPU 69 32 NITS Application 1423

Delivery Point Name Ownership Voltage (kV)

LAMAR 2 MIPU 69 HARRIS MIPU 161 LONEJAC MIPU 161 NRAYMOR MIPU 161 NCONGRS5 MIPU 161 CONCORD2 MIPU 69 BELTONS MIPU 161 PECULR2 MIPU 69 SAMPSON MIPU 161 RTCHFLD MIPU 161 RAYMORE MIPU 69 POPE MIPU 161 COOKING MIPU 161 ALABAMA MIPU 161 EDMOND5 MIPU 161 MRVL#2 MIPU 69 BURLJCT MIPU 69 TARKIO_ MIPU 69 FAIRFAX MIPU 69 CRAIG_2 MIPU 69 MNDCITY MIPU 69 BRWNCRV MIPU 69 KELLOG_ MIPU 69 MRVL#1 MIPU 69 PICKRG_ MIPU 69 NODAWAY MIPU 69 FILMORE MIPU 69 HONEYWL5 MIPU 161 CNTRVIEW2 MIPU 69 EASTOWN5 MIPU 161

33 NITS Application 1423

APPENDIX 3

Evergy Missouri West, Inc. Eve and Richards, MO Delivery Points

(a) (b) (c) (d) (e) SPP Bus Delivery Point of Meter Ownership Meter Voltage Number / Point Name Delivery [kV] Measured Name Voltage (Location) [kV] (1) (2) 533635 City of 12.5 Evergy Kansas Central, Inc. 12.5 FTSCOTT2 Eve, MO (Circuit)/(d) 69 kV 533635 City of 12.5 Evergy Kansas Central, Inc. 12.5 FTSCOTT2 Richards, (Circuit)/(d) 69 kV MO

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Appendix 4 Wholesale Distribution Service Charge Calculations

35 NITS Application 1423

APPENDIX 4

Evergy Missouri West, Inc. Wholesale Distribution Service Charge July 2019

Delivery Point Facility Facility Cost Facility Facility Metered Loss Share of Facility MW Cost Per MW Adjusted Cost Demand MW Demand MW Demand Richards Circuit SK7217 12-04 $357,563.30 6.2000 $57,671.50 0.0870 0.0888 $5,122.28 Sub SK7217 Fort Scott $146,066.60 9.6000 $15,215.27 0.0870 0.0888 $1,351.39 Eve Circuit SK7217 12-04 $162,502.14 6.2000 $26,210.02 0.1142 0.1166 $3,055.74 Sub SK7217 Fort Scott $146,066.60 9.6000 $15,215.27 0.1142 0.1166 $1,773.90

Total Facility Cost 2020 Net Plant Carrying Charge Monthly Wholesale Distribution Service Charge

$11,303.32 1.0600% $119.82

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Wholesale Distribution Service Charge Support

Delivery Point Circuit Circuit Feet Circuit Circuit Cost Dollars Per Foot Eve Circuit SK7217 12-04 27,735 $5.8591 $162,502.14 Richards Circuit SK7217 12-04 61,027 $5.8591 $357,563.30

Delivery Point Metered Distribution Distribution Loss MW Loss Factor Adjusted MW Demand* Demand Eve 0.1142 1.0209 0.1166 Richards 0.0870 1.0209 0.0888

*Metered Demand at Peak 07/19/2019 05:00 PM

37 NITS Application 1423

Attachment A

Reserved for future use.

38 NITS Application 1423

ATTACHMENT B AGREEMENT FOR THE PROVISION OF

TRANSMISSION SERVICE TO MISSOURI BUNDLED RETAIL LOAD

This AGREEMENT FOR THE PROVISION OF TRANSMISSION SERVICE

TO MISSOURI BUNDLED RETAIL LOAD (hereinafter the “Agreement”) is entered into as of this ______day of ______2009, by and between Southwest Power Pool,

Inc. (“SPP”) and KCP&L Greater Missouri Operations Company (“KCP&L-GMO”).

WITNESSETH:

WHEREAS, SPP is a FERC-approved Regional Transmission Organization

(“RTO”) with an open architecture that accommodates various forms of participation by transmission owning utilities; and

WHEREAS, KCP&L-GMO currently maintains open-access transmission tariffs approved by the FERC; and

39 NITS Application 1423

WHEREAS, KCP&L-GMO currently provides and will continue to provide

Bundled Electric Service (including capacity, energy, transmission and distribution) to

Missouri Bundled Retail Load pursuant to rates established by the Missouri Public

Service Commission (“MoPSC”) and in accord with certain tariffs and rate schedules on file with the MoPSC; and

Agreement referred to below, KCP&L-GMO plans to utilize Network Integration

Transmission Service from SPP, while this Agreement is in effect, in order to provide the transmission services necessary to furnish Bundled Electric Service to Missouri Bundled

Retail Load; and

1 WHEREAS, the FERC, in various orders and in its White Paper, Wholesale

WHEREAS, the Parties hereto desire to codify the specific terms and conditions stated herein under which SPP will provide Network Integration Transmission Service to

KCP&L-GMO to serve its Missouri Bundled Retail Load in addition to the terms and

1 Cleco Power, et al., 103 FERC ¶ 61,272 (2003), and Midwest Indep. Trans. System Operator, Inc., 102 FERC ¶ 61,192 (2003).

40 NITS Application 1423 conditions set forth in SPP’s NITSA and NOA except as otherwise stated in this

Agreement.

ARTICLE I - DEFINITIONS

Section 1.2 Missouri Bundled Retail Load: The load of retail electric customers of KCP&L-GMO in the State of Missouri, on whose behalf and to whom

KCP&L-GMO, by statute, franchise, regulatory requirement or contract, has an obligation to provide Bundled Electric Service.

Section 1.3 SPP Membership Agreement: The Southwest Power Pool, Inc.

Membership Agreement (SPP’s Original Volume No. 3), as amended from time to time in accordance with its terms.

Section 1.4 SPP OATT: The open-access transmission tariff of SPP (SPP’s

FERC Electric Tariff, Fifth Revised Volume No. 1), as amended from time to time.

41 NITS Application 1423

ARTICLE II - FILING, EFFECTIVE DATE, INITIAL TERM AND TERMINATION

Section 2.1 As soon as practicable following the execution of this Agreement,

42 NITS Application 1423

Section 2.3 This Agreement shall remain in effect following the Effective Date for an initial term ending the earlier of: (i) the date that KCP&L-GMO withdraws from

SPP, or (ii) at 12:00:01 a.m., on October 1, 2013. Subject to the termination provisions of this Section 2.3, the Initial Term shall automatically be extended from year to year (a

Agreement affect in any way the rights or obligations of SPP to enforce or seek the enforcement of any terms in its Membership Agreement, Bylaws and OATT relating to any withdrawal by KCP&L-GMO.

ARTICLE III - RATE FOR TRANSMISSION SERVICE TO SERVE MISSOURI BUNDLED RETAIL LOAD

Section 3.1 Schedule 9 of the SPP OATT establishes a zonal transmission rate applicable to load within the KCP&L-GMO pricing zone that is taking Network

Load using its own facilities, and does not voluntarily submit to such jurisdiction.

KCP&L-GMO shall not pay the rate set forth in Schedule 9 of the SPP OATT for using its own facilities to serve its Missouri Bundled Retail Load, but will include Missouri

43 NITS Application 1423

Bundled Retail Load in the total load used to calculate the zonal rate for the KCP&L-

GMO zone. However, this provision shall not eliminate any obligation that KCP&L-

GMO may have to pay applicable charges related to facilities owned by other entities in

KCP&L-GMO’s zone that are unaffiliated with KCP&L-GMO.

OATT. With regard to Schedules 1 and 2, KCP&L-GMO shall not be required to pay

Section 3.3 Except as otherwise provided in Sections 3.1 and 3.2, KCP&L-

Attachments H, J, K, M, U, V, Z, AE, and AK and Schedules 1A, 4 (to the extent

Schedule 4 reflects the energy costs associated with SPP’s Energy Imbalance Services market), 11, and 12 of the SPP OATT.

Transmission Service.

44 NITS Application 1423

ARTICLE IV - MISCELLANEOUS

Section 4.1 The obligations of the Parties shall be binding on and inure to the benefit of their respective successors and assigns.

Section 4.3 This Agreement may be executed in one or more counterparts, each of which shall be deemed an original, and all of which shall constitute one and the same instrument.

Section 4.4 Every notice, consent or approval required or permitted under this

45 NITS Application 1423

If to KCP&L-GMO, to:

Vice President – Transmission Policy, Planning and Compliance 1201 Walnut, 21st Floor Kansas City, Missouri 64106 Fax No. (816) 556-2924

If to SPP, to:

President Southwest Power Pool, Inc. 415 North McKinley, Suite 140 Little Rock, Arkansas 72205-3020 Fax No. (501) 664-9553

IN WITNESS WHEREOF, the Parties have caused this Agreement to be executed by their respective authorized officials.

KCP&L Greater Missouri Operations Company

By: /s/ Richard A. Spring Richard A. Spring Vice President – Transmission Policy, Planning and Compliance Southwest Power Pool, Inc.

By: /s/ Nick Brown Nicholas A. (Nick) Brown President and CEO

46 NITS Application 1423

NETWORK OPERATING AGREEMENT AMONG SOUTHWEST POWER POOL, INC., EVERGY METRO, INC., EVERGY MISSOURI WEST, INC. AND EVERGY KANSAS CENTRAL, INC.

This Network Operating Agreement ("Operating Agreement") is entered into this 1st day of February, 2021, by and between Evergy Metro, Inc. ("Network Customer"), Southwest Power Pool, Inc. ("Transmission Provider"), Evergy Missouri West, Inc. ("Host Transmission Owner"), Evergy Metro, Inc. ("Host Transmission Owner"), and Evergy Kansas Central, Inc. ("Host Transmission Owner"). The Network Customer, Transmission Provider and Host Transmission Owners shall be referred to individually as a "Party" and collectively as "Parties." WHEREAS, the Transmission Provider has determined that the Network Customer has made a valid request for Network Integration Transmission Service in accordance with the Transmission Provider’s Open Access Transmission Tariff ("Tariff") filed with the Federal Energy Regulatory Commission ("Commission"); WHEREAS, the Transmission Provider administers Network Integration Transmission Service for Transmission Owners within the SPP Region and acts as an agent for these Transmission Owners in providing service under the Tariff; WHEREAS, the Host Transmission Owner(s) owns the transmission facilities to which the Network Customer’s Network Load is physically connected; WHEREAS, the Network Customer has represented that it is an Eligible Customer under the Tariff; WHEREAS, the Network Customer and Transmission Provider have entered into a Network Integration Transmission Service Agreement (“Service Agreement”) under the Tariff; and WHEREAS, the Parties intend that capitalized terms used herein shall have the same meaning as in the Tariff, unless otherwise specified herein. NOW, THEREFORE, in consideration of the mutual covenants and agreements herein, the Parties agree as follows:

47 NITS Application 1423

1.0 Network Service

This Operating Agreement sets out the terms and conditions under which the Transmission Provider, Host Transmission Owners, and Network Customer will cooperate and the Host Transmission Owners and Network Customer will operate their respective systems and specifies the equipment that will be installed and operated. The Parties shall operate and maintain their respective systems in a manner that will allow the Host Transmission Owners and the Network Customer to operate their systems and the Transmission Provider to perform its obligations consistent with Good Utility Practice. The Transmission Provider may, on a non-discriminatory basis, waive the requirements of Section 4.1 and Section 8.3 to the extent that such information is unknown at the time of application or where such requirement is not applicable. 2.0 Designated Representatives of the Parties

2.1 Each Party shall designate a representative and alternate ("Designated Representative(s)") from their respective company to coordinate and implement, on an ongoing basis, the terms and conditions of this Operating Agreement, including planning, operating, scheduling, redispatching, curtailments, control requirements, technical and operating provisions, integration of equipment, hardware and software, and other operating considerations. 2.2 The Designated Representatives shall represent the Transmission Provider, Host Transmission Owners, and Network Customer in all matters arising under this Operating Agreement and which may be delegated to them by mutual agreement of the Parties hereto. 2.3 The Designated Representatives shall meet or otherwise confer at the request of any Party upon reasonable notice, and each Party may place items on the meeting agenda. All deliberations of the Designated Representatives shall be conducted by taking into account the exercise of Good Utility Practice. If the Designated Representatives are unable to agree on any matter subject to their deliberation, that matter shall be resolved pursuant to Section 12.0 of the Tariff, or otherwise, as mutually agreed by the Parties.

48 NITS Application 1423

3.0 System Operating Principles

3.1 The Network Customer must design, construct, and operate its facilities safely and efficiently in accordance with Good Utility Practice, NERC, SPP, or any successor requirements, industry standards, criteria, and applicable manufacturer’s equipment specifications, and within operating physical parameter ranges (voltage schedule, load power factor, and other parameters) required by the Host Transmission Owners and Transmission Provider. 3.2 The Host Transmission Owners and Transmission Provider reserve the right to inspect the facilities and operating records of the Network Customer upon mutually agreeable terms and conditions. 3.3 Electric service, in the form of three phase, approximately sixty hertz alternating current, shall be delivered at designated delivery points and nominal voltage(s) listed in the Service Agreement. When multiple delivery points are provided to a specific Network Load identified in Appendix 3 of the Service Agreement, they shall not be operated in parallel by the Network Customer without the approval of the Host Transmission Owners and Transmission Provider. The Designated Representatives shall establish the procedure for obtaining such approval. The Designated Representatives shall also establish and monitor standards and operating rules and procedures to assure that transmission system integrity and the safety of customers, the public and employees are maintained or enhanced when such parallel operations is permitted either on a continuing basis or for intermittent switching or other service needs. Each Party shall exercise due diligence and reasonable care in maintaining and operating its facilities so as to maintain continuity of service. 3.4 The Host Transmission Owners and Network Customer shall operate their systems and delivery points in continuous synchronism and in accord with applicable NERC Standards, SPP Criteria, and Good Utility Practice. 3.5 If the function of any Party’s facilities is impaired or the capacity of any delivery point is reduced, or synchronous operation at any delivery point(s) becomes interrupted, either manually or automatically, as a result of force majeure or maintenance coordinated by the Parties, the Parties will cooperate to remove the

49 NITS Application 1423

cause of such impairment, interruption or reduction, so as to restore normal operating conditions expeditiously. 3.6 The Transmission Provider and Host Transmission Owners, if applicable, reserve the sole right to take any action necessary during an actual or imminent emergency to preserve the reliability and integrity of the Transmission System, limit or prevent damage, expedite restoration of service, ensure safe and reliable operation, avoid adverse effects on the quality of service, or preserve public safety. 3.7 In an emergency, the reasonable judgment of the Transmission Provider and Host Transmission Owners, if applicable, in accordance with Good Utility Practice, shall be the sole determinant of whether the operation of the Network Customer loads or equipment adversely affects the quality of service or interferes with the safe and reliable operation of the transmission system. The Transmission Provider or Host Transmission Owners, if applicable, may discontinue transmission service to such Network Customer until the power quality or interfering condition has been corrected. Such curtailment of load, redispatching, or load shedding shall be done on a non-discriminatory basis by Load Ratio Share, to the extent practicable. The Transmission Provider or Host Transmission Owners, if applicable, will provide reasonable notice and an opportunity to alleviate the condition by the Network Customer to the extent practicable. 4.0 System Planning & Protection

4.1 No later than October 1 of each year, the Network Customer shall provide the Transmission Provider and Host Transmission Owners the following information: a) A ten (10) year projection of summer and winter peak demands with the corresponding power factors and annual energy requirements on an aggregate basis for each delivery point. If there is more than one delivery point, the Network Customer shall provide the summer and winter peak demands and energy requirements at each delivery point for the normal operating configuration; b) A ten (10) year projection by summer and winter peak of planned generating capabilities and committed transactions with third parties

50 NITS Application 1423

which resources are expected to be used by the Network Customer to supply the peak demand and energy requirements provided in (a); c) A ten (10) year projection by summer and winter peak of the estimated maximum demand in kilowatts that the Network Customer plans to acquire from the generation resources owned by the Network Customer, and generation resources purchased from others; and d) A projection for each of the next ten (10) years of transmission facility additions to be owned and/or constructed by the Network Customer which facilities are expected to affect the planning and operation of the transmission system within the Host Transmission Owners’ Zones. This information is to be delivered to the Transmission Provider’s and Host Transmission Owners’ Designated Representatives pursuant to Section 2.0. 4.2 Information exchanged by the Parties under this article will be used for system planning and protection only, and will not be disclosed to third parties absent mutual consent or order of a court or regulatory agency. 4.3 The Host Transmission Owners, and Transmission Provider, if applicable, will incorporate this information in its system load flow analyses performed during the first half of each year. Following completion of these analyses, the Transmission Provider or Host Transmission Owners will provide the following to the Network Customer: a) A statement regarding the ability of the Host Transmission Owners’ transmission system to meet the forecasted deliveries at each of the delivery points; b) A detailed description of any constraints on the Host Transmission Owners’ system within the five (5) year horizon that will restrict forecasted deliveries; and c) In the event that studies reveal a potential limitation of the Transmission Provider’s ability to deliver power and energy to any of the delivery points, a Designated Representative of the Transmission Provider will coordinate with the Designated Representatives of the Host Transmission Owners and the Network Customer to identify appropriate remedies for

51 NITS Application 1423

such constraints including but not limited to: construction of new transmission facilities, upgrade or other improvements to existing transmission facilities or temporary modification to operating procedures designed to relieve identified constraints. Any constraints within the Transmission System will be remedied pursuant to the procedures of Attachment O of the Tariff. For all other constraints the Host Transmission Owners, upon agreement with the Network Customer and consistent with Good Utility Practice, will endeavor to construct and place into service sufficient capacity to maintain reliable service to the Network Customer. An appropriate sharing of the costs to relieve such constraints will be determined by the Parties, consistent with the Tariff and with the Commission’s rules, regulations, policies, and precedents then in effect. If the Parties are unable to agree upon an appropriate remedy or sharing of the costs, the Transmission Provider shall submit its proposal for the remedy or sharing of such costs to the Commission for approval consistent with the Tariff. 4.4 The Host Transmission Owners and the Network Customer shall coordinate with the Transmission Provider: (1) all scheduled outages of generating resources and transmission facilities consistent with the reliability of service to the customers of each Party, and (2) additions or changes in facilities which could affect another Party’s system. Where coordination cannot be achieved, the Designated Representatives shall intervene for resolution. 4.5 The Network Customer shall coordinate with the Host Transmission Owners regarding the technical and engineering arrangements for the delivery points, including one line diagrams depicting the electrical facilities configuration and parallel generation, and shall design and build the facilities to avoid interruptions on the Host Transmission Owners’ transmission system. 4.6 The Network Customer shall provide for automatic and underfrequency load shedding of the Network Customer Network Load in accordance with the SPP Criteria related to emergency operations.

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5.0 Maintenance of Facilities

5.1 The Network Customer shall maintain its facilities necessary to reliably receive capacity and energy from the Host Transmission Owners’ transmission system consistent with Good Utility Practice. The Transmission Provider or Host Transmission Owners, as appropriate, may curtail service under this Operating Agreement to limit or prevent damage to generating or transmission facilities caused by the Network Customer’s failure to maintain its facilities in accordance with Good Utility Practice, and the Transmission Provider or Host Transmission Owners may seek as a result any appropriate relief from the Commission. 5.2 The Designated Representatives shall establish procedures to coordinate the maintenance schedules, and return to service, of the generating resources and transmission and substation facilities, to the greatest extent practical, to ensure sufficient transmission resources are available to maintain system reliability and reliability of service. 5.3 The Network Customer shall obtain: (1) concurrence from the Transmission Provider before beginning any scheduled maintenance of facilities which could impact the operation of the Transmission System over which transmission service is administered by Transmission Provider; and (2) clearance from the Transmission Provider when the Network Customer is ready to begin maintenance on a transmission line or substation. The Transmission Provider shall coordinate clearances with the Host Transmission Owners. The Network Customer shall notify the Transmission Provider and the Host Transmission Owners as soon as practical at the time when any unscheduled or forced outages occur and again when such unscheduled or forced outages end. 6.0 Scheduling Procedures

6.1 The Network Customer is responsible for providing its Resource and load information to the Transmission Provider in accordance with Attachment AE. 6.2 For Interchange Transactions the Network Customer shall submit, or arrange to have submitted, the schedule of Energy to or from the Transmission Provider and a transaction identification E-Tag for each such schedule where required by NERC Standard INT-001.

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7.0 Ancillary Services

7.1 The Network Customer must make arrangements in appropriate amounts for all of the required Ancillary Services described in the Tariff. The Network Customer must obtain these services from the Transmission Provider or, where applicable, self-supply or obtain these services from a third party. 7.2 Where the Network Customer elects to self-supply or have a third party provide Ancillary Services, the Network Customer must demonstrate to the Transmission Provider that it has either acquired the Ancillary Services from another source or is capable of self-supplying the services. 7.3 The Network Customer must designate the supplier of Ancillary Services. 8.0 Metering

8.1 The Network Customer shall provide for the installation of meters, associated metering equipment and telemetering equipment. The Network Customer shall permit (or provide for, if the Network Customer is not the meter owner) the Transmission Provider’s and Host Transmission Owners’ representative to have access to the equipment at all reasonable hours and for any reasonable purpose, and shall not permit unauthorized persons to have access to the space housing the equipment. Network Customer shall provide to (or provide for, if the Network Customer is not the meter owner) the Host Transmission Owners access to load data and other data available from any delivery point meter. If the Network Customer does not own the meter, the Host Transmission Owners shall make available, upon request, all load data and other data obtained by the Host Transmission Owners from the relevant delivery point meter, if available utilizing existing equipment. The Network Customer will cooperate on the installation of advanced technology metering in place of the standard metering equipment at a delivery point at the expense of the requestor; provided, however, that meter owner shall not be obligated to install, operate or maintain any meter or related equipment that is not approved for use by the meter owner and/or Host Transmission Owners, and provided that such equipment addition can be accomplished in a manner that does not interfere with the operation of the meter

54 NITS Application 1423

owner’s equipment or any Party’s fulfillment of any statutory or contractual obligation. 8.2 The Network Customer shall provide for the testing of the metering equipment at suitable intervals and its accuracy of registration shall be maintained in accordance with standards acceptable to the Transmission Provider and consistent with Good Utility Practice. At the request of the Transmission Provider or Host Transmission Owners, a special test shall be made, but if less than two percent inaccuracy is found, the requesting Party shall pay for the test. Representatives of the Parties may be present at all routine or special tests and whenever any readings for purposes of settlement are taken from meters not having an automated record. If any test of metering equipment discloses an inaccuracy exceeding two percent, the accounts of the Parties shall be adjusted. Such adjustment shall apply to the period over which the meter error is shown to have been in effect or, where such period is indeterminable, for one-half the period since the prior meter test. Should any metering equipment fail to register, the amounts of energy delivered shall be estimated from the best available data. 8.3 If the Network Customer is supplying energy to retail load that has a choice in its supplier, the Network Customer shall be responsible for providing all information required by the Transmission Provider for billing purposes. Metering information shall be available to the Transmission Provider either by individual retail customer or aggregated retail energy information for that load the Network Customer has under contract during the billing month. For the retail load that has interval demand metering, the actual energy used by interval must be supplied. For the retail load using standard kWh metering, the total energy consumed by meter cycle, along with the estimated demand profile must be supplied. All rights and limitations between Parties granted in Sections 8.1, and 8.2 are applicable in regards to retail metering used as the basis for billing the Network Customer.

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9.0 Connected Generation Resources

9.1 The Network Customer’s connected generation resources that have automatic generation control and automatic voltage regulation shall be operated and maintained consistent with regional operating standards, and the Network Customer or the operator shall operate, or cause to be operated, such resources to avoid adverse disturbances or interference with the safe and reliable operation of the transmission system as instructed by the Transmission Provider. 9.2 For all Network Resources of the Network Customer, the following generation telemetry readings shall be submitted to the Transmission Provider and Host Transmission Owners: 1) Analog MW; 2) Integrated MWHRS/HR; 3) Analog MVARS; and 4) Integrated MVARHRS/HR. 10.0 Redispatching, Curtailment and Load Shedding

10.1 In accordance with Section 33 of the Tariff, the Transmission Provider may require redispatching of Resources to relieve existing or potential transmission system constraints. The Transmission Provider shall redispatch Resources in accordance with the Energy and Operating Reserve Markets operations specified in Attachment AE. The Network Customer shall respond immediately to requests for redispatch from the Transmission Provider. The Transmission Provider will bill or credit the Network Customer as appropriate using the settlement procedures specified in Attachment AE. 10.2 The Parties shall implement load-shedding procedures to maintain the reliability and integrity for the Transmission System as provided in Section 33.1 of the Tariff and in accordance with applicable NERC and SPP requirements and Good Utility Practice. Load shedding may include (1) automatic load shedding, (2) manual load shedding, and (3) rotating interruption of customer load. When manual load shedding or rotating interruptions are necessary, the Host Transmission Owners shall notify the Network Customer’s dispatcher or

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schedulers of the required action and the Network Customer shall comply immediately. 10.3 The Network Customer will coordinate with the Host Transmission Owners to ensure sufficient load shedding equipment is in place on their respective systems to meet SPP requirements. The Network Customer and the Host Transmission Owners shall develop a plan for load shedding which may include manual load shedding by the Network Customer. 11.0 Communications

11.1 The Network Customer shall, at its own expense, install and maintain communication link(s) for scheduling. The communication link(s) shall be used for data transfer and for voice communication. 11.2 A Network Customer self-supplying Ancillary Services or securing Ancillary Services from a third-party shall, at its own expense, install and maintain telemetry equipment communicating between the generating resource(s) providing such Ancillary Services and the Host Transmission Owners’ Zones. 12.0 Cost Responsibility

12.1 The Network Customer shall be responsible for all costs incurred by the Network Customer, Host Transmission Owners, and Transmission Provider to implement the provisions of this Operating Agreement including, but not limited to, engineering, administrative and general expenses, material and labor expenses associated with the specification, design, review, approval, purchase, installation, maintenance, modification, repair, operation, replacement, checkouts, testing, upgrading, calibration, removal, and relocation of equipment or software, so long as the direct assignment of such costs is consistent with Commission policy. 12.2 The Network Customer shall be responsible for all costs incurred by Network Customer, Host Transmission Owners, and Transmission Provider for on-going operation and maintenance of the facilities required to implement the provisions of this Operating Agreement so long as the direct assignment of such costs is consistent with Commission policy. Such work shall include, but is not limited to, normal and extraordinary engineering, administrative and general expenses, material and labor expenses associated with the specifications, design, review,

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approval, purchase, installation, maintenance, modification, repair, operation, replacement, checkouts, testing, calibration, removal, or relocation of equipment required to accommodate service provided under this Operating Agreement. 13.0 Billing and Payments

Any dispute among the Parties regarding this Operating Agreement shall be resolved pursuant to Section 12 of the Tariff, or otherwise, as mutually agreed by the Parties. 15.0 Assignment

This Operating Agreement shall inure to the benefit of and be binding upon the Parties and their respective successors and assigns, but shall not be assigned by any Party, except to successors to all or substantially all of the electric properties and assets of such Party, without the written consent of the other Parties. Such written consent shall not be unreasonably withheld. 16.0 Choice of Law

The interpretation, enforcement, and performance of this Operating Agreement shall be governed by the laws of the State of Arkansas, except laws and precedent of such jurisdiction concerning choice of law shall not be applied, except to the extent governed by the laws of the United States of America. 17.0 Entire Agreement

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18.0 Unilateral Changes and Modifications

Nothing contained in this Operating Agreement or any associated Service Agreement shall be construed as affecting in any way the right of the Transmission Provider or a Transmission Owners unilaterally to file with the Commission, or make application to the Commission for, changes in rates, charges, classification of service, or any rule, regulation, or agreement related thereto, under section 205 of the Federal Power Act and pursuant to the Commission’s rules and regulations promulgated thereunder, or under other applicable statutes or regulations. Nothing contained in this Operating Agreement or any associated Service Agreement shall be construed as affecting in any way the ability of any Network Customer receiving Network Integration Transmission Service under the Tariff to exercise any right under the Federal Power Act and pursuant to the Commission’s rules and regulations promulgated thereunder; provided, however, that it is expressly recognized that this Operating Agreement is necessary for the implementation of the Tariff and Service Agreement. Therefore, no Party shall propose a change to this Operating Agreement that is inconsistent with the rates, terms and conditions of the Tariff and/or Service Agreement. 19.0 Term

This Operating Agreement shall become effective on the date assigned by the Commission (“Effective Date”), and shall continue in effect until the Tariff or the Network Customer’s Service Agreement is terminated, whichever shall occur first. 20.0 Notice

20.1 Any notice that may be given to or made upon any Party by any other Party under any of the provisions of this Operating Agreement shall be in writing, unless otherwise specifically provided herein, and shall be considered delivered when the notice is personally delivered or deposited in the United States mail, certified or registered postage prepaid, to the following:

Transmission Provider Southwest Power Pool, Inc. Tessie Kentner Attorney

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201 Worthen Drive Little Rock, AR 72223-4936 Phone: (501) 688-1782 Email Address: [email protected]

Host Transmission Owner: Evergy Kansas Central, Inc. Bruce Akin Vice President– Transmission & Distribution 818 S. Kansas Ave. Topeka, KS 66612 Phone: (785) 575-6354 Email Address: [email protected]

Host Transmission Owner: Evergy Missouri West, Inc. Bruce Akin Vice President– Transmission & Distribution 818 S. Kansas Ave. Topeka, KS 66612 Phone: (785) 575-6354 Email Address: [email protected]

Host Transmission Owner: Evergy Metro, Inc. Bruce Akin Vice President – Transmission & Distribution 818 S. Kansas Ave. Topeka, KS 66612 Phone: (785) 575-6354 Email Address: [email protected]

Network Customer: Evergy Metro, Inc. Kevin Noblet Vice President – Safety and Operations Planning P.O. Box 418679 Kansas City, MO 64141 Phone: (816) 701-7811 Email Address: [email protected]

Any Party may change its notice address by written notice to the other Parties in accordance with this Article 20. 20.2 Any notice, request, or demand pertaining to operating matters may be delivered in writing, in person or by first class mail, e-mail, messenger, or facsimile

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transmission as may be appropriate and shall be confirmed in writing as soon as reasonably practical thereafter, if any Party so requests in any particular instance. 21.0 Execution in Counterparts

This Operating Agreement may be executed in any number of counterparts with the same effect as if all Parties executed the same document. All such counterparts shall be construed together and shall constitute one instrument.

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IN WITNESS WHEREOF, the Parties have caused this Operating Agreement to be executed by their respective authorized officials, and copies delivered to each Party, to become effective as of the Effective Date.

TRANSMISSION PROVIDER HOST TRANSMISSION OWNER Evergy Metro, Inc.

/s/ Lanny Nickell /s/ Bruce A. Akin Signature Signature

Lanny Nickell Bruce A. Akin Printed Name Printed Name

EVP & COO VP, Transmission and Distribution Title Title

11/18/2020 11/6/20 Date Date

HOST TRANSMISSION OWNER HOST TRANSMISSION OWNER Evergy Missouri West, Inc. Evergy Kansas Central, Inc.

/s/ Bruce A. Akin /s/ Bruce A. Akin Signature Signature

Bruce A. Akin Bruce A. Akin Printed Name Printed Name

VP, Transmission and Distribution VP, Transmission and Distribution Title Title

11/6/20 11/6/2020 Date Date

NETWORK CUSTOMER Evergy Metro, Inc.

/s/ Kevin Noblet Signature

Kevin Noblet Printed Name

Vice President, Safety & Operations Title

11/10/2020 Date

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Southwest Power Pool, Inc. Twenty-Third Revised Service Agreement No. 1276

SERVICE AGREEMENT FOR NETWORK INTEGRATION TRANSMISSION SERVICE BETWEEN SOUTHWEST POWER POOL, INC. AND EVERGY METRO, INC.

This Network Integration Transmission Service Agreement ("Service Agreement") is entered into this 1st day of FebruaryMarch, 2021, by and between Evergy Metro, Inc. ("Network Customer"), and Southwest Power Pool, Inc. ("Transmission Provider"). The Network Customer and Transmission Provider shall be referred to individually as “Party” and collectively as "Parties." WHEREAS, the Transmission Provider has determined that the Network Customer has made a valid request for Network Integration Transmission Service in accordance with the Transmission Provider’s Open Access Transmission Tariff ("Tariff") filed with the Federal Energy Regulatory Commission ("Commission") as it may from time to time be amended; WHEREAS, the Transmission Provider administers Network Integration Transmission Service for Transmission Owners within the SPP Region and acts as agent for the Transmission Owners in providing service under the Tariff; WHEREAS, the Network Customer has represented that it is an Eligible Customer under the Tariff; and WHEREAS, the Parties intend that capitalized terms used herein shall have the same meaning as in the Tariff. NOW, THEREFORE, in consideration of the mutual covenants and agreements herein, the Parties agree as follows:

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TRANSMISSION PROVIDER NETWORK CUSTOMER

/s/ Lanny Nickell /s/ Kevin Noblet Signature Signature

Lanny Nickell Kevin Noblet Printed Name Printed Name

Vice President, Safety and Operations Planning, Evergy EVP & COO Metro, Inc. Title Title

3-11-2021 3-2-2021 Date Date

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ATTACHMENT 1 TO THE NETWORK INTEGRATION TRANSMISSION SERVICE AGREEMENT

BETWEEN SOUTHWEST POWER POOL, INC. AND EVERGY METRO, INC. SPECIFICATIONS FOR NETWORK INTEGRATION TRANSMISSION SERVICE

The loads of Network Customer identified in Section 2.0 hereof as the Network Load are electrically located within the Kansas City Power & Light, Kansas City Power & Light Greater Missouri Operations Company, and Westar Zone(s). 6.0 Delivery Points The delivery points are the interconnection points identified in Section 2.0 as the Network Load. 7.0 Receipt Points The Points of Receipt are listed in Appendix 2. 8.0 Compensation Service under this Service Agreement may be subject to some combination of the charges detailed below. The appropriate charges for individual transactions will be determined in accordance with the terms and conditions of the Tariff. 8.1 Transmission Charge Monthly Demand Charge per Section 34 and Part V of the Tariff shall be treated pursuant to the Missouri Agreement. 8.2 System Impact and/or Facility Study Charge Studies may be required in the future to assess the need for system reinforcements in light of the ten-year forecast data provided. Future charges, if required, shall be in accordance with Section 32 of the Tariff. 8.3 Direct Assignment Facilities Charge 8.4 Ancillary Service Charges 8.4.1 The following Ancillary Services are required under this Service Agreement. a) Scheduling System Control and Dispatch Service per Schedule 1 of the Tariff. b) Tariff Administration Service per Schedule 1-AA1 of the Tariff. c) Reactive Supply and Voltage Control from Generation Sources Service per Schedule 2 of the Tariff. d) Regulation and Frequency Response Service per Schedule 3 of the Tariff. e) Energy Imbalance Service per Schedule 4 of the Tariff. f) Operating Reserve - Spinning Reserve Service per Schedule 5 of the Tariff. g) Operating Reserve - Supplemental Reserve Service per Schedule 6 of the Tariff.

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requiring Network Upgrades.

Upgrade Name Upgrade Description Transmission Owner Need Date SWISSVALE - Replace Terminal Equipment WERE 6/1/2021 WEST GARDNER 345KV CKT 1 WERE

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Planned Project

Upgrade Name Upgrade Description Transmission Owner Need Date SWISSVALE - Replace Terminal Equipment WERE 6/1/2021 WEST GARDNER 345KV CKT 1 WERE

Planned Project

Upgrade Name Upgrade Description Transmission Owner Need Date SWISSVALE - Replace Terminal Equipment WERE 6/1/2021 WEST GARDNER 345KV CKT 1 WERE

Planned Project

Upgrade Name Upgrade Description Transmission Owner Need Date SWISSVALE - Replace terminal equipment. WERE 6/1/2017 WEST GARDNER 345KV CKT 1 WERE

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Planned Project

Upgrade Name Upgrade Description Transmission Owner Need Date SWISSVALE - Replace terminal equipment. WERE 6/1/2017 WEST GARDNER 345KV CKT 1 WERE

Potential System Constraints Projects

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APPENDIX 1

Network Resources of Evergy Metro, Inc.

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APPENDIX 1 EVERGY METRO, INC. NETWORK RESOURCES

Firm Network Resource Service Start Service Transmission Comments Name Date End Date Rights 75 MW of capacity rights CROSSROADS 1 68/1/2015 6/1/2030 75 MW untilto 6/1/2032 75 MW of capacity rights CROSSROADS 2 68/1/2015 6/1/2030 75 MW untilto 6/1/2032 75 MW of capacity rights CROSSROADS 3 68/1/2015 6/1/2030 75 MW untilto 6/1/2032 75 MW of capacity rights CROSSROADS 4 68/1/2015 6/1/2030 75 MW untilto 6/1/2032 GREENWOOD 1 68/1/2015 6/1/2030 63 MW GREENWOOD 2 68/1/2015 6/1/2030 61 MW GREENWOOD 3 68/1/2015 6/1/2030 66 MW GREENWOOD 4 68/1/2015 6/1/2030 63 MW HAWTHORN 5 68/1/2015 6/1/2030 563 MW HAWTHORN 6 68/1/2015 6/1/2030 162 MW HAWTHORN 7 68/1/2015 6/1/2030 90 MW HAWTHORN 8 68/1/2015 6/1/2030 90 MW HAWTHORN 9 68/1/2015 6/1/2030 130 MW IATAN 1_KCPL 68/1/2015 6/1/2030 501 MW IATAN 1_MPS 68/1/2015 6/1/2030 127 MW IATAN 2_MPS 68/1/2015 6/1/2030 162 MW IATAN 2_KCPL 68/1/2015 6/1/2030 500 MW JEFFREY EC 1 68/1/2015 6/1/2030 58 MW 612/1/201520 JEFFREY EC 2 6/1/2030 59 MW 17 JEFFREY EC 3 68/1/2015 6/1/2030 58 MW LACYGNE 1 68/1/2015 6/1/2030 370 MW LACYGNE 2 68/1/2015 6/1/2030 341 MW LAKE RD 1 68/1/2015 6/1/2030 22 MW LAKE RD 2 68/1/2015 6/1/2030 27 MW LAKE RD 3 68/1/2015 6/1/2030 11 MW LAKE RD 4 68/1/2015 6/1/2030 99 MW LAKE RD CT 5 68/1/2015 6/1/2030 62 MW LAKE RD JE 6 68/1/2015 6/1/2030 21 MW LAKE RD JE 7 68/1/2015 6/1/2030 22 MW NEVADA 68/1/2015 6/1/2030 21 MW NORTHEAST 11 68/1/2015 6/1/2030 63 MW NORTHEAST 12 68/1/2015 6/1/2030 63 MW NORTHEAST 13 68/1/2015 6/1/2030 65 MW NORTHEAST 14 68/1/2015 6/1/2030 65 MW 23 NITS Application 1423

NORTHEAST 15 68/1/2015 6/1/2030 65 MW NORTHEAST 16 68/1/2015 6/1/2030 65 MW NORTHEAST 17 68/1/2015 6/1/2030 65 MW NORTHEAST 18 68/1/2015 6/1/2030 65 MW NORTHEAST BLACK START 68/1/2015 6/1/2030 2 MW GENERATOR OSAWATOMIE CT 1 68/1/2015 6/1/2030 90 MW RALPH GREEN 3 68/1/2015 6/1/2030 72 MW SOUTH HARPER 1 68/1/2015 6/1/2030 105 MW SOUTH HARPER 2 68/1/2015 6/1/2030 106 MW SOUTH HARPER 3 68/1/2015 6/1/2030 104 MW 1/23/2020 6/1/2021 0 MW TWA 1 6/1/2021 6/1/2030 17 MW 6/1/202120 1/24/2020 0 MW TWA 2 22 6/1/20212022 17 MW 6/1/2030 WEST GARDNER CT 1 68/1/2015 6/1/2030 90 MW WEST GARDNER CT 2 68/1/2015 6/1/2030 90 MW WEST GARDNER CT 3 68/1/2015 6/1/2030 90 MW WEST GARDNER CT 4 68/1/2015 6/1/2030 90 MW WOLF CREEK 68/1/2015 6/1/2030 568 MW 200 MW of capacity WAVERLY WIND 10/1/2015 6/1/2030 200 MW rights until 4/1/2036 NPPD JEFFREY 1 PURCHASE 68/1/2015 1/1/2025 20 MW NPPD JOHNSON 1 PURCHASE 68/1/2015 1/1/2025 20 MW NPPD JOHNSON 2 PURCHASE 68/1/2015 1/1/2025 22 MW WESTAR POWER PURCHASE 68/1/2015 6/1/2030 1 MW 132 MW capacity rights 6/1/2032 69/1/2015 132 MW until 6/1/2032 CIMARRON WIND PURCHASE 4/1/203320 6/1/20322018 32 MW 32 MW capacity rights 30 6/1/2032 to 4/1/2033 100 MW of capacity ENSIGN WIND 68/1/2015 6/1/2030 100 MW rights until 4/1/2033 610/1/201520 110 MW of capacity GRAY COUNTY WIND 6/1/2030 110 MW 19 rights until 12/1/2031 SPEARVILLE WIND 50 MW of capacity rights 68/1/2015 6/1/2030 50 MW PURCHASE 1 until 4/1/2033 SPEARVILLE WIND 68/1/2015 6/1/2030 101 MW PURCHASE 2 SPEARVILLE WIND 6/1/1/2022 1/1/2017 50 MW PURCHASE 3 2030 SPEARVILLE WIND 6/1/1/2022 1/1/2017 50 MW PURCHASE 4 2030 SLATE CREEK WIND 150 MW of capacity 3/1/2016 6/1/2030 150 MW PURCHASE rights until 9/1/2036 ROCK CREEK WIND 12/31/20161/1 6/1/2030 300 MW 300 MW of capacity 24 NITS Application 1423

PURCHASE /2017 rights until 12/31/20371/1/2038 200 MW of capacity 12/31/20161/1 OSBORN WIND PURCHASE 6/1/2030 200 MW rights until /2017 12/31/20371/1/2038 200 MW of capacity PRAIRIE QUEEN WIND 34/1/2019 6/1/2030 200 MW rights until 6/1/2039 245 MW of capacity PRATT WIND 1/1/2019 6/1/2030 245 MW rights until 6/1/2049

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Appendix 2

Receipt Points of Evergy Metro, Inc.

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APPENDIX 2 EVERGY METRO, INC. RECEIPT POINTS

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Appendix 3

Delivery Points of Evergy Metro, Inc.

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Appendix 3 Delivery Points

Delivery Point Name Ownership Voltage (kV)

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APPENDIX 3

Evergy Missouri West, Inc. Eve and Richards, MO Delivery Points

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Appendix 4 Wholesale Distribution Service Charge Calculations

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APPENDIX 4

Evergy Missouri West, Inc. Wholesale Distribution Service Charge July 2019

Total Facility Cost 2020 Net Plant Carrying Charge Monthly Wholesale Distribution Service Charge

$11,303.32 1.0600% $119.82

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Wholesale Distribution Service Charge Support

Delivery Point Circuit Circuit Feet Circuit Circuit Cost Dollars Per Foot Eve Circuit SK7217 12-04 27,735 $5.8591 $162,502.14 Richards Circuit SK7217 12-04 61,027 $5.8591 $357,563.30

Delivery Point Metered Distribution Distribution Loss MW Loss Factor Adjusted MW Demand* Demand Eve 0.1142 1.0209 0.1166 Richards 0.0870 1.0209 0.0888

*Metered Demand at Peak 07/19/2019 05:00 PM

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Attachment A

Reserved for future use.

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ATTACHMENT B AGREEMENT FOR THE PROVISION OF

TRANSMISSION SERVICE TO MISSOURI BUNDLED RETAIL LOAD

This AGREEMENT FOR THE PROVISION OF TRANSMISSION SERVICE

TO MISSOURI BUNDLED RETAIL LOAD (hereinafter the “Agreement”) is entered into as of this ______day of ______2009, by and between Southwest Power Pool,

Inc. (“SPP”) and KCP&L Greater Missouri Operations Company (“KCP&L-GMO”).

WITNESSETH:

WHEREAS, SPP is a FERC-approved Regional Transmission Organization

(“RTO”) with an open architecture that accommodates various forms of participation by transmission owning utilities; and

WHEREAS, KCP&L-GMO currently maintains open-access transmission tariffs approved by the FERC; and

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WHEREAS, KCP&L-GMO currently provides and will continue to provide

Bundled Electric Service (including capacity, energy, transmission and distribution) to

Missouri Bundled Retail Load pursuant to rates established by the Missouri Public

Service Commission (“MoPSC”) and in accord with certain tariffs and rate schedules on file with the MoPSC; and

Agreement referred to below, KCP&L-GMO plans to utilize Network Integration

Transmission Service from SPP, while this Agreement is in effect, in order to provide the transmission services necessary to furnish Bundled Electric Service to Missouri Bundled

Retail Load; and

1 WHEREAS, the FERC, in various orders and in its White Paper, Wholesale

WHEREAS, the Parties hereto desire to codify the specific terms and conditions stated herein under which SPP will provide Network Integration Transmission Service to

KCP&L-GMO to serve its Missouri Bundled Retail Load in addition to the terms and

1 Cleco Power, et al., 103 FERC ¶ 61,272 (2003), and Midwest Indep. Trans. System Operator, Inc., 102 FERC ¶ 61,192 (2003).

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Agreement.

ARTICLE I - DEFINITIONS

Section 1.2 Missouri Bundled Retail Load: The load of retail electric customers of KCP&L-GMO in the State of Missouri, on whose behalf and to whom

KCP&L-GMO, by statute, franchise, regulatory requirement or contract, has an obligation to provide Bundled Electric Service.

Section 1.3 SPP Membership Agreement: The Southwest Power Pool, Inc.

Membership Agreement (SPP’s Original Volume No. 3), as amended from time to time in accordance with its terms.

Section 1.4 SPP OATT: The open-access transmission tariff of SPP (SPP’s

FERC Electric Tariff, Fifth Revised Volume No. 1), as amended from time to time.

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ARTICLE II - FILING, EFFECTIVE DATE, INITIAL TERM AND TERMINATION

Section 2.1 As soon as practicable following the execution of this Agreement,

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Section 2.3 This Agreement shall remain in effect following the Effective Date for an initial term ending the earlier of: (i) the date that KCP&L-GMO withdraws from

SPP, or (ii) at 12:00:01 a.m., on October 1, 2013. Subject to the termination provisions of this Section 2.3, the Initial Term shall automatically be extended from year to year (a

Agreement affect in any way the rights or obligations of SPP to enforce or seek the enforcement of any terms in its Membership Agreement, Bylaws and OATT relating to any withdrawal by KCP&L-GMO.

ARTICLE III - RATE FOR TRANSMISSION SERVICE TO SERVE MISSOURI BUNDLED RETAIL LOAD

Section 3.1 Schedule 9 of the SPP OATT establishes a zonal transmission rate applicable to load within the KCP&L-GMO pricing zone that is taking Network

Load using its own facilities, and does not voluntarily submit to such jurisdiction.

KCP&L-GMO shall not pay the rate set forth in Schedule 9 of the SPP OATT for using its own facilities to serve its Missouri Bundled Retail Load, but will include Missouri

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Bundled Retail Load in the total load used to calculate the zonal rate for the KCP&L-

GMO zone. However, this provision shall not eliminate any obligation that KCP&L-

GMO may have to pay applicable charges related to facilities owned by other entities in

KCP&L-GMO’s zone that are unaffiliated with KCP&L-GMO.

OATT. With regard to Schedules 1 and 2, KCP&L-GMO shall not be required to pay

Section 3.3 Except as otherwise provided in Sections 3.1 and 3.2, KCP&L-

Attachments H, J, K, M, U, V, Z, AE, and AK and Schedules 1A, 4 (to the extent

Schedule 4 reflects the energy costs associated with SPP’s Energy Imbalance Services market), 11, and 12 of the SPP OATT.

Transmission Service.

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ARTICLE IV - MISCELLANEOUS

Section 4.1 The obligations of the Parties shall be binding on and inure to the benefit of their respective successors and assigns.

Section 4.3 This Agreement may be executed in one or more counterparts, each of which shall be deemed an original, and all of which shall constitute one and the same instrument.

Section 4.4 Every notice, consent or approval required or permitted under this

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If to KCP&L-GMO, to:

Vice President – Transmission Policy, Planning and Compliance 1201 Walnut, 21st Floor Kansas City, Missouri 64106 Fax No. (816) 556-2924

If to SPP, to:

President Southwest Power Pool, Inc. 415 North McKinley, Suite 140 Little Rock, Arkansas 72205-3020 Fax No. (501) 664-9553

IN WITNESS WHEREOF, the Parties have caused this Agreement to be executed by their respective authorized officials.

KCP&L Greater Missouri Operations Company

By: /s/ Richard A. Spring Richard A. Spring Vice President – Transmission Policy, Planning and Compliance Southwest Power Pool, Inc.

By: /s/ Nick Brown Nicholas A. (Nick) Brown President and CEO

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NETWORK OPERATING AGREEMENT AMONG SOUTHWEST POWER POOL, INC., EVERGY METRO, INC., EVERGY MISSOURI WEST, INC. AND EVERGY KANSAS CENTRAL, INC.

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1.0 Network Service

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3.0 System Operating Principles

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5.0 Maintenance of Facilities

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7.0 Ancillary Services

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9.0 Connected Generation Resources

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Any dispute among the Parties regarding this Operating Agreement shall be resolved pursuant to Section 12 of the Tariff, or otherwise, as mutually agreed by the Parties. 15.0 Assignment

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18.0 Unilateral Changes and Modifications

Transmission Provider Southwest Power Pool, Inc. Tessie Kentner Attorney

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201 Worthen Drive Little Rock, AR 72223-4936 Phone: (501) 688-1782 Email Address: [email protected]

Host Transmission Owner: Evergy Missouri West, Inc. Bruce Akin Vice President– Transmission & Distribution 818 S. Kansas Ave. Topeka, KS 66612 Phone: (785) 575-6354 Email Address: [email protected]

Host Transmission Owner: Evergy Metro, Inc. Bruce Akin Vice President – Transmission & Distribution 818 S. Kansas Ave. Topeka, KS 66612 Phone: (785) 575-6354 Email Address: [email protected]

Network Customer: Evergy Metro, Inc. Kevin Noblet Vice President – Safety and Operations Planning P.O. Box 418679 Kansas City, MO 64141 Phone: (816) 701-7811 Email Address: [email protected]

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transmission as may be appropriate and shall be confirmed in writing as soon as reasonably practical thereafter, if any Party so requests in any particular instance. 21.0 Execution in Counterparts

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TRANSMISSION PROVIDER HOST TRANSMISSION OWNER Evergy Metro, Inc.

/s/ Lanny Nickell /s/ Bruce A. Akin Signature Signature

Lanny Nickell Bruce A. Akin Printed Name Printed Name

EVP & COO VP, Transmission and Distribution Title Title

11/18/2020 11/6/20 Date Date

HOST TRANSMISSION OWNER HOST TRANSMISSION OWNER Evergy Missouri West, Inc. Evergy Kansas Central, Inc.

/s/ Bruce A. Akin /s/ Bruce A. Akin Signature Signature

Bruce A. Akin Bruce A. Akin Printed Name Printed Name

VP, Transmission and Distribution VP, Transmission and Distribution Title Title

11/6/20 11/6/2020 Date Date

NETWORK CUSTOMER Evergy Metro, Inc.

/s/ Kevin Noblet Signature

Kevin Noblet Printed Name

Vice President, Safety & Operations Title

11/10/2020 Date

62 NITS Application 1423