Transmission Rate Information

These transmission rates are effective as of the date of their posting and will not reflect any retroactive adjustments due to FERC Orders or any other reasons.


Transmission Service Rates

Historical Rate Information








March 1, 2019:

Rate changes were processed to incorporate the following:

These changes are effective March 1, 2019.

February 22, 2019:

Rate changes were processed to incorporate the following:

These changes are effective February 1, 2019.

January 29, 2019:

Rate changes were processed to incorporate the annual revenue requirements and/or divisor updates of Attachments O/GG/MM/ZZ for Transmission Owner using a forward-looking Attachment O. MHEB provided updates for their rates. Two new schedules were also added, Schedule 26-C and Schedule 26-D (Targeted Market Efficiency Projects – TMEP).

December 1, 2018:

Rate changes were processed to incorporate the following:

These changes are effective December 1, 2018.


November 18, 2018:

Rate changes were processed to incorporate the following: The Transco ROE Adder component was lowered to 25 basis points per Docket EL18-140 for ITC, ITCM, and METC. This change affects the following schedules; These changes are effective November 1, 2018.

October 18, 2018:

Rate changes were processed to incorporate the following: These changes are effective October 1, 2018.

September 19, 2018:

Rate changes were processed to incorporate the following: These changes are effective September 1, 2018.

August 16, 2018:

Rate changes were processed to incorporate the following: These changes are effective August 1, 2018.

July 19, 2018:

Rate changes were processed to incorporate the following: These changes are effective July 1, 2018.

June 20, 2018:

Transmission rate changes were processed to incorporate the Annual Updates of the historical Transmission Owners, which includes updating the Attachments O and GG. The following schedules changed: 1, 2, 7, 8, 9, 26, 33, 37, 38, 41, 42-B, and 45.

In addition to divisor and revenue requirement updates, other changes reflected in the rate update include the following:


The overall impact on MISO system rates follows: These changes are effective June 1, 2018.

May 22, 2018:

Rate changes were processed to incorporate the following: These changes are effective May 1, 2018.

April 23, 2018:

Rate changes were processed to incorporate the following: These changes are effective April 1, 2018.

March 23, 2018:

Per docket ER18-783, rate changes were processed to incorporate the updated 2018 projected Attachments O/GG/MM/ZZ net revenue requirements for certain MISO Transmission Owners to reflect recent tax law changes included in the Tax Cuts and Jobs Act, approved by Congress on 12/22/17. For purposes of this update, the certain MISO Transmission Owners reflecting a reduction in federal corporate tax rate (and other related changes, as applicable) include the following:

Additional changes reflected in the update include the following:

The following schedules changed: 2, 7, 8, 9, 26, 26-A, 37, 38, and 45.

The overall impact on MISO system rates follows:

These changes are effective March 1, 2018.

February 23, 2018:

Rate changes were processed to incorporate the following:

These changes are effective February 1, 2018.

January 26, 2017:

Rate changes were processed to incorporate the annual revenue requirements and/or load updates of Attachments O/GG/MM/ZZ for Transmission Owners using a forward-looking Attachment O. Additional changes reflected in the update include the following:

The following schedules changed: 1, 2, 7, 8, 9, 26, 26-A, 33, 37, 38, 42A and 45.

The overall impact on MISO system rates follows:

These changes are effective January 1, 2018.

December 11, 2017:

Rate changes were processed to incorporate the following:

These changes are effective December 1, 2017.

November 17, 2017:

Rate changes were processed to incorporate the following:

These changes are effective November 1, 2017.

October 19, 2017:

Rate changes were processed to incorporate the following:

These changes are effective October 1, 2017.

September 20, 2017:

Rate changes were processed to incorporate the following::

These changes are effective September 1, 2017.

Augest 18, 2017:

Rate changes were processed to incorporate the following::

These changes are effective August 1, 2017.

July 25, 2017:

Rate changes were processed to incorporate the following::

These changes are effective July 1, 2017.

June 21, 2017:

Transmission rate changes were processed to incorporate the June Updates of Attachments O, GG, and MM for the historical Transmission Owners. The following schedules changed: 1, 2, 7, 8, 9, 26, 26-A, 33, 37, 38, 41, 42-A, 42-B, and 45. Other changes reflected in the rate update include the following:

These changes are effective June 1, 2017.

May 24, 2017:

Rate changes were processed to incorporate the following:

These changes are effective May 1, 2017.

April 19, 2017:

Rate changes were processed to incorporate the following:

EL14-12 ROE resettlement - to incorporate revised 2015 true-up adjustments on a prospective basis. This affected Schedules 7, 8, 9, 26, 26-A, 37, 38, & 45. Other changes reflected in the rate update include the following:

The overall impact on MISO system rates follows:

These changes are effective April 1, 2017.



March 15, 2017:

Rate changes were processed to incorporate the following:

These changes are effective March 1, 2017.



February 17, 2017:

Rate changes were processed to incorporate the following:

These changes are effective February 1, 2017.



January 26, 2017:

Rate changes were processed to incorporate the January updates of Attachments O/GG/MM/ZZ for Transmission Owners using a forward-looking Attachment O.  Additional changes reflected in the update include the following:


The following schedules changed: 1, 2, 7, 8, 9, 26, 26-A, 33, 37, 38, 41, and 45.

The overall impact on MISO system rates follows:

These changes are effective January 1, 2017.



December 6, 2016:

Rate changes were processed to incorporate the following:

These changes are effective December 1, 2016.



November 16, 2016:

Rate changes were processed to incorporate the following:

These changes are effective November 1, 2016.



October 25, 2016:

Rate changes were processed to incorporate the following:

These changes are effective October 1, 2016.



September 21, 2016:

Rate changes were processed to incorporate the following:

These changes are effective September 1, 2016.



August 17, 2016:

Rate changes were processed to incorporate the following:

These changes are effective August 1, 2016.



July 21, 2016:

Rate changes were processed to incorporate the following:

These changes are effective July 1, 2016.



June 22, 2016:

Transmission rate changes were processed to incorporate the June Annual Updates of Attachments O / GG and Schedules 1 / 33 / 41 / 42-A / 42-B for the Historical Test Year Transmission Owners.  Other changes reflected in the rate update include the following:

These changes are effective June 1, 2016.



May 18, 2016:

Rate changes were processed to incorporate the following:

These changes are effective May 1, 2016.



April 27, 2016:

Rate changes were processed to incorporate the following:

These changes are effective April 1, 2016.



March 16, 2016:

Rate changes were processed to incorporate the following:

These changes are effective March 1, 2016.



February 20, 2016:

Rate changes were processed to incorporate the following:


The following schedules changed: 2, 7, 8, 9, and 47.

The overall impact on MISO system rates follows:

	Schedule 2:			0.08% increase
	Schedules 7, 8, & 9:		0.00% increase
	Schedule 47:			There is no MISO system-wide rate for this schedule

These changes are effective February 1, 2016.



January 22, 2016:

Transmission rate changes were processed to incorporate the following:

The following schedules changed: 1, 2, 7, 8, 9, 26, 26-A, 33, 36, 37, 38, and 45.

The overall impact on MISO system rates follows:

	Schedule 1:		17.48% increase
	Schedule 2:		1.92% increase
	Schedules 7, 8, & 9:	5.48% increase
	Schedule 26:		6.93% increase
	Schedule 33:		0.25% increase
	Schedule 45:		1.83% increase

The overall impact on MISO system rates follows:

	Schedule 1:		21.97% decrease
	Schedule 2:		21.97% decrease
	Schedules 7, & 8:	21.97% decrease
	Schedule 7A:		21.97% decrease
	Schedule 11:		1.33% decrease
	Schedule 9 (NITS):	Removed

These changes are effective January 1, 2016.



December 4, 2015:

Transmission rate changes were processed to incorporate the following:

These actions resulted in changes to Schedules 1, 2, 7, 8, 9, 26, 33, 41, 42A, 42B, 45 and 47 for MISO.

Overall, the impact on the MISO system rate is an increase of 2.48% for Schedules 7, 8, and 9.

These changes are effective November 1, 2015.



October 21, 2015:

Transmission rate changes were processed to incorporate the following:

This resulted in the following Sch. 2 rate impacts:

These changes are effective October 1, 2015.



September 18, 2015:

MISO Tariff Pricing has incorporated the following Rate changes to the MISO September 2015 Transmission Rate Update:

Transmission rate changes were processed to incorporate the following:

This resulted in the following Sch. 2 rate impacts:

These changes are effective September 1, 2015.



August 25, 2015:

MISO Tariff Pricing has incorporated the following Rate changes to the MISO August 2015 Transmission Rate Update:

Transmission rate changes were processed to incorporate the following:

This resulted in the following Sch. 2 rate impacts:

These changes are effective August 1, 2015.



July 17, 2015:

MISO Tariff Pricing has incorporated the following Rate changes to the MISO July 2015 Transmission Rate Update:

Transmission rate changes were processed to incorporate the following:

This resulted in the following Sch. 2 rate impacts:

Correction of Big Rivers Attachment O divisor. This change affected Schedules 1, 2, 7, 8, 9, 26, 33, and 45. The impact on the MISO average rate from this divisor correction was (0.03%).

These changes are effective July 1, 2015.



June 26, 2015:

Transmission rate changes were processed to incorporate the June Updates of Attachments O & GG for the historical Transmission Owners. An exception was made for the Entergy OpCos. Per an ER13-948 waiver granted on 5/20/15, the rates for the Entergy OpCos will not be updated until 9/1/15. Other changes reflected in the rate update include the following:

The following schedules changed: 1, 2, 7, 8, 9, 26, 33, 37, 38, and 45. Overall, the impact on the MISO system rate is an increase of 1.13% for Schedules 7, 8, and 9. These changes are effective June 1, 2015.



May 21, 2015:

MISO Tariff Pricing has incorporated the following Rate changes to the MISO May 2015 Transmission Rate Update:

The Schedule 2 Revenue Requirement was modified for the Pine Bluff Energy Center as a result of an Interim Rate Order issued on 4/27/15 in Docket ER14-2762. The revenue requirement was lowered to $750,000. This resulted in the following Sch. 2 rate impacts:

These changes are effective May 1, 2015.



April 14, 2015:

MISO Tariff Pricing has incorporated the following Rate changes to the MISO April 2015 Transmission Rate Update:

The overall impact on MISO Sch. 2 rates is an increase of 2.79%.

These changes are effective April 1, 2015.



March 20, 2015:

MISO Tariff Pricing has incorporated the following Rate changes to the MISO March 2015 Transmission Rate Update:

The overall impact on MISO Sch. 2 rates is a decrease of 2.13%.

These changes are effective March 1, 2015.



February 23, 2015:

MISO Tariff Pricing has incorporated the following Rate changes to the MISO February 2015 Transmission Rate Update:

The overall impact on MISO Sch. 2 rates is an increase of 0.32%.

These changes are effective February 1, 2015.



January 23, 2015:

MISO Tariff Pricing has processed the MISO January 2015 Transmission Rate Update with the following reasons:

Rate changes were processed to incorporate the January updates of Attachment O/GG/MM/SS/ZZ for Transmission Owner's using a forward-looking Attachment O. Other changes reflected in the update include the following:

The following schedules changed: 1, 2, 7, 8, 9, 26, 26-A, 33, 36, 37, 38, and 45.

The overall impact on MISO system rates follows:

	Schedule 1:		2.9% decrease
	Schedule 2:		1.06% decrease
	Schedules 7, 8, & 9:	2.59% increase
	Schedule 26:		11.46% increase

Attached are the updated Schedules

These changes are effective January 1, 2015.



December 17, 2014:

MISO Tariff Pricing has processed the MISO December 2014 Transmission Rate Update with the following reasons:

The following schedules changed: 1, 2, 7, 8, 9, 26, 33, and 45.

Overall, the impact on the MISO system rate is an increase of 0.19% for Schedules 7, 8, and 9.

Attached are the updated Schedules.

These changes are effective December 1, 2014.



November 24, 2014:

MISO Tariff Pricing has processed the MISO November 2014 Transmission Rate Update with the following changes:

This resulted in a 3.00% increase in Schedule 2 MISO system-wide average rate.

These changes are effective November 1, 2014.



September 24, 2014:

MISO Tariff Pricing has processed the MISO September 2014 Transmission Rate Update with the following changes:

Overall, the impact on the MISO system rate is an increase of 0.02% for Schedules 7, 8, and 9.

These changes are effective September 1, 2014.



August 25, 2014:

MISO Tariff Pricing has processed the MISO August 2014 Transmission Rate Update with the following change:

This change resulted in a 1.56% increase in the Schedule 2 MISO system-wide average rate.

These changes are effective August 1, 2014.



June 26, 2014:

MISO Tariff Pricing has processed the MISO June 2014 Transmission Rate Update with the following Rate changes to incorporate the June Updates of Attachments O & GG for the historical Transmission Owners. Other changes reflected in the rate update include the following:

The following schedules changed: 1,2,7,8,9,26,33,37,38,41,42-A,42-B, and 45. One new Schedule (Schedule 47) was added.

Overall, the impact on the MISO system rate is an increase of 3.17% for Schedules 7, 8, and 9.

These changes are effective June 1, 2014.



June 23, 2014:

MISO Tariff Pricing has processed the MISO June 2014 Transmission Rate Update with the following changes:

The following schedules changed: 1,2,7,8,9,26,33,37,38,41,42-A,42-B, and 45. One new Schedule (Schedule 47) was added.

Overall, the impact on the MISO system rate is an increase of 3.16% for Schedules 7, 8, and 9.

These changes are effective June 1, 2014.



May 23, 2014:

MISO Tariff Pricing has incorporated the MISO May 2014 Transmission Rate Update with the following changes:

Overall, the impact on the MISO system rate is a decrease of 0.19% for Schedule 2.

These changes are effective May 1, 2014.



April 22, 2014:

MISO Tariff Pricing has processed the MISO April 2014 Transmission Rate Update with the following changes:

Overall, the impact on the MISO system rate is an increase of 9.3% for schedule 33.

These changes are effective April 1, 2014.



March 25, 2014:

MISO Tariff Pricing has processed the MISO March 2014 Transmission Rate Update with the following changes:

Overall, the impact on the MISO system rate is a decrease of 0.02% for Schedules 7 and 8.

These changes are effective March 1, 2014.



February 24, 2014:

MISO Tariff Pricing has processed the MISO February 2014 Transmission Rate Update with the following changes:

Overall, the impact on the MISO system rate is a decrease of 0.0181 % for Schedule 2.

These changes are effective February 1, 2014.



February 3, 2014:

MISO Tariff Pricing has processed a revision to the Schedule 1 rate for January 2014. This information replaces the data posted on 1/24/2014.

Rate changes were processed to incorporate the January updates of Attachments O/GG/MM/SS for the projected test year Transmission Owners. Other changes reflected in this rate update include the following:

These actions resulted in changes to Schedules 1, 2, 7, 8, 9, 26, 26-A, 33, 36, 37, and 38 for MISO and the creation of 1 new Schedule (Schedule 45).

Overall, the impact on the MISO system rate is an increase of 27.26% for Schedule 2; 3.55% for Schedules 7, 8, and 9, and 19.69% for Schedule 26.

These changes are effective January 1, 2014.



January 24, 2014:

Rate changes were processed to incorporate the January updates of Attachments O/GG/MM/SS for the projected test year Transmission Owners. Other changes reflected in this rate update include the following:

These actions resulted in changes to Schedules 1, 2, 7, 8, 9, 26, 26-A, 33, 36, 37, and 38 for MISO and the creation of 1 new Schedule (Schedule 45).

Overall, the impact on the MISO system rate is an increase of 27.26% for Schedule 2; 3.55% for Schedules 7, 8, and 9, and 19.69% for Schedule 26.

These changes are effective January 1, 2014.



December 30, 2013:

Rate changes were processed to reflect the integration of the Southern Region into MISO. This includes 13 new Attachment O’s and the addition of 7 new pricing zones as follows:

Schedule 2 was also revised to incorporate a new generator (CLECO) and its stated rate to the CLECO zone. (OA96-15).

These actions resulted in changes to Schedules 1, 2, 7, 8, 9, 26, and 33 for MISO and the creation of 3 new Schedules (Schedule 41, 42-A, and 42-B – (EC12-145)).

Overall, the impact on the MISO system rate is a decrease of 7.72% for Schedules 7, 8, and 9.

These changes are effective for the period December 19th – 31st, 2013.



December 17, 2013:

A rate update was processed to incorporate the following revision to Schedule 2:

Added Revenue Requirement for a new generator (Hillman facility) to the METC pricing zone. Pursuant to ER13-2076/EL13-89 and subsequent settlement proceedings, Hillman's Revenue Requirement agreed upon in Article II of the Settlement was accepted and authorized interim rates, and will remain in effect pending full Commission approval of the Settlement.

The overall impact on the MISO system rate is an increase of .0356% for Schedule 2.

These changes are effective December 1, 2013.



November 26, 2013:

Processed a NERC ID change from AMEM to AMDV, coincident with the asset transfer between them (for the Gibson City and Grand Tower units; no impact to Sch 2 rates from this transaction).

Added 9 new generators Revenue Requirements to the Big Rivers Pricing Zone, effective 11/1/13 (EL13-85: Coleman – Units 1, 2, 3; Green Station – Units 1, 2; Wilson Station – Unit 1; Reid Station – Unit 1; Reid Station – CT; and HMPL – Station 2)

These changes are effective November 1, 2013.



September 18, 2013:

A rate update was processed to incorporate the addition of a Transmission Owner, Worthington Public Utilities (WPU), in the ITC Midwest (ITCM) pricing zone. WPU is already included in the ITCM forecasted load, therefore no load adjustments have been made.

These actions resulted in changes to Schedules 7, 8, and 9. Overall, the impact on the MISO system rate is an increase of .02% for Schedules 7, 8, and 9.

These changes are effective September 1, 2013.



August 05, 2013:

For the July 26, 2013 Transmission Rate Update, the Price by Sink tab has been updated to include Schedule 33 rates for PJM. There were no changes to rates from the original July 26, 2013 posting.

These changes are effective July 1, 2013.



July 26, 2013:

Rate changes were processed to incorporate the initial rate calculation for implementation of a new schedule - Schedule 33 Blackstart Service - for Wisconsin Electric Power Company (NERC ID WEPM). The revenue requirement which provides the foundation for this rate calculation was approved in ER12-2678.

These changes are effective July 1, 2013.



June 17, 2013:

Rate changes were processed to incorporate the June Updates of Attachments O & GG for the historical Transmission Owners. Other changes reflected in this rate update include the following:

These actions resulted in changes to Schedules 1, 2, 7, 8, 9, 26, 37, and 38 for MISO; in addition to all of the Interface Rates.

Overall, the impact on the MISO system rate is an increase of 3.59% for Schedules 7, 8, and 9; an increase of 1.1% for Schedule 26.

These changes are effective June 1, 2013.



May 23, 2013:

A rate change was processed to amend the Schedule 2 Revenue Requirement for Dynegy Midwest Generation LLC (DMG). The Commission’s April 11, 2013 Order (ER13-974) accepted DMG’s revised revenue requirement for providing Reactive Supply and Voltage Control from Generation Sources Service related to the retirement of the Oglesby and Stallings generating facilities. This action resulted in a change to the Schedule 2 rate.

The overall impact on the MISO system rate is a decrease of .0179% for Schedule 2.

This change is effective May 1, 2013.



January 22, 2013:

Rate changes were processed to incorporate the January Updates of Attachments O / GG / MM for the projected test year Transmission Owners. Other changes reflected in this rate update include the following:

These actions resulted in changes to Schedules 1, 2, 7, 8, 9, 26, 36, 37, and 38 for MISO; in addition to all of the Interface Rates.

Overall, the impact on the Midwest ISO system rate is an increase of 5.09% for Schedules 7, 8 and 9; an increase of 27.72% for Schedule 26.

These changes are effective January 1, 2013.



December 17, 2012:

A rate change was processed to incorporate the Schedule 2 Revenue Requirements accepted by FERC for the ownership portions of Unit # 2 of the Prairie State Energy Campus (PSEC) for the following entities:

This action resulted in a change to the Schedule 2 rate, effective 12/1/12.

The overall impact on the MISO system rate is an increase of 1.37% for Schedule 2.



November 5, 2012:

A rate change was processed to incorporate the Schedule 2 Revenue Requirements accepted by FERC for the ownership portions of Unit # 1 of the Prairie State Energy Campus (PSEC) for the following entities:

This action resulted in a change to the Schedule 2 rate, effective 10/1/12.

The overall impact on the MISO system rate is an increase of 1.38% for Schedule 2.

These changes are effective October 1, 2012.



October 26, 2012:

A rate change was processed to incorporate the Schedule 2 Revenue Requirement accepted by FERC for Lively Grove Energy Partners (LGEP) portion of Unit # 1 of the Prairie State Energy Campus (PSEC) in Docket # ER12-2353. This action resulted in a change to the Schedule 2 rate, effective 10/1/12.

The overall impact on the MISO system rate is an increase of 0.07% for Schedule 2.

These changes are effective October 1, 2012.



September 26, 2012:

Rate changes were processed to incorporate the newly Re-Delineated 69 kV Transmission assets of Pella, Atlantic, Cedar Falls, and Waverly. Indianola was added as a 30.9 customer in the MEC Pricing Zone, as part of this 69 kV Re-Delineation. This classification change was approved by FERC in Docket # EL12-57. GRE moved load from the ITCM Pricing Zone to the SMMPA Pricing Zone. Please note that there was no change to the ITCM zonal divisor. GRE also moved transmission assets from the ITCM Pricing Zone to the GRE Pricing Zone. Corrections related to the removal of merger-related expenses were incorporated into Duke-Indiana’s Attachments O and GG. Similar corrections to Duke-Ohio’s Attachment GG were processed. These corrections will be implemented in September, 2012; and billing adjustments will be processed back to June, 2012. Finally, Schedule 1 was modified and approved (subject to a compliance filing) to be a Zonal Rate construct in FERC Docket ER12-2129. All of these actions resulted in changes to Schedules 1, 2, 7, 8, 9, 26, 37, and 38; in addition to all of the Interface Rates.

The overall impact on the MISO system rate is a decrease of 0.636% for Schedules 7, 8, and 9; and a decrease of 0.015% for Schedule 26.

These changes are effective September 1, 2012.



August 24, 2012:

Rate changes were processed to incorporate a correction to Vectren’s 2012 Attachment GG. This correction resulted in changes to the rates for Schedules 26, 37, and 38. The revised rates will be implemented in August, 2012; and billing adjustments will be processed back to January, 2012. These billing adjustments will be processed in the near future.

The overall impact on the MISO Schedule 26 rate is a decrease of 0.04%.

These changes are effective August 1, 2012.



July 30, 2012:

Rate changes were processed to incorporate the midyear update of the Capacity Benefit Margin (CBM) values. The CBM data impacts the divisor calculation for the Schedule 1 rate and the Schedules 7 & 8 Drive - Through and Out rates.

The overall impact on the MISO Schedule 1 rate is a decrease of 0.7%. The Drive -Through and Out rates for Schedules 7 and 8 also decreased 0.7%. The Zonal rates for all Schedules remain unchanged.

These changes are effective July 1, 2012.



June 19, 2012:

Rate changes were processed to incorporate the June Updates of Attachment O / GG for the historical test year Transmission Owners. These actions resulted in changes to Schedules 1, 2, 7, 8, 9, 26, 37, and 38; in addition to all of the Interface Rates.

The overall impact on the MISO system rate is an increase of 0.94% for Schedules 7, 8, and 9; and an increase of 4.21% for Schedule 26.

Dairyland Power Cooperative notified MISO of their intent to retire the Alma 1 – 3 generating units, effective 6/1/12. In retirement, these units are no longer capable of providing reactive power, and Dairyland no longer claims compensation under Schedule 2 of the MISO Tariff. MISO removed the revenue requirement related to these units effective June 1, 2012. The divisor for the Schedule 2 rate calculation was also updated as part of the June Attachment O update for historical test year Transmission Owners.

The MISO average Schedule 2 rate decreased by 0.11%.

These changes are effective June 1, 2012.



April 26, 2012:

Ameren Illinois Company (AIC) proposed revisions to its Attachment O to allow inclusion of the annual transmission revenue requirement (ATRR) and transmission credits (Section 30.9) associated with Prairie Power, Inc.’s (PPI) transmission facilities located in the Ameren Illinois pricing zone. The proposed tariff revisions were accepted, effective April 1, 2012. The rates for Schedules 7, 8, 9, and all of the Interface rates are impacted by this order (FERC Docket ER12-310).

The overall impact on the MISO system rate is an increase of 0.02% for Schedules 7, 8, and 9.

MISO will begin billing PJM and NYISO under Schedule 36 for their portion of the cost of the Bunce Creek (B3N) Phase Angle Regulators (PARs) effective April 5, 2012. The FERC order in Docket ER11-1844 authorized this billing to begin when the PARs were placed into commercial service. International Transmission Company (ITC) posted a notice on their OASIS page announcing that the PARs were placed in commission at 1000 hours EDT on April 5, 2012. MISO will generate partial month invoices in April, and full month invoices thereafter.

Midland Cogeneration Venture (MCV) reached an agreement to lower their annual Schedule 2 revenue requirement from $7.9 M to $6.0 M. FERC approved the settlement on March 20, 2012, retroactive back to June 1, 2011 in Docket ER11-3035. MISO is implementing the change in rates effective April 1, 2012. Billing adjustments to reflect the retroactive impact of this order are in the process of being implemented.

A NERC ID change for the Tilton generation facilities was implemented effective April 1, 2012. NERC ID TERM has been replaced by EAGL, for revenue distribution purposes.

The overall impact of the rate revision was a decrease of 1.24% for Schedule 2.

These changes are effective April 1, 2012.



March 30, 2012:

Ameren Transmission Company of Illinois (ATXI) was approved to transition from a transmission revenue requirement calculated on an historical basis to a forward-looking formula rate and to implement transmission incentive rate treatments previously approved by the Commission in connection with a new transmission project, the Illinois Rivers Project, to become effective March 1, 2012. The rates for Schedules 7, 8, 9, 26-A, and all of the Interface rates are impacted by this order (FERC Docket ER12-749).

The overall impact on the MISO system rate is a decrease of 0.02% for Schedules 7, 8, and 9. The 2012 Sch. 26-A annual revenue requirement increased by $1,143,454, after adding the ATXI MVP projects.

Duke Energy Vermillion II, LLC (Duke Vermillion’s) Notice of Termination of its Sch. 2 Tariff was accepted with a January 17, 2012 effective date (FERC Docket ER12-815). This change is being implemented in March, 2012. MISO will make a retroactive billing adjustment for the month of February, 2012.

The overall impact of the rate revision was a decrease of 0.71% for Schedule 2.

These changes are effective March 1, 2012.



February 28, 2012:

Dairyland Power Cooperative (DPC) filed for a revised rate schedule for reactive power revenue requirement pursuant to Schedule 2 of the MISO Tariff on 11/30/11. The Sch. 2 Revenue Requirement revision for the Elk Mound Unit 1 & 2 generators was approved on 1/18/12 with a 2/1/12 effective date. We also had a NERC ID change on the Calpine RockGen generator. NERC ID ROCK was replaced by CALP effective 2/1/12.

The overall impact of the rate revision was an increase of 0.05%.

Vectren submitted a correction of their 2012 estimate for Schedule 1 (Scheduling, System Control, and Dispatch Service) Expenses. This correction also affects January, 2012. We will process a retroactive rate adjustment in the near future.

This expense increase caused an overall increase of 1.8% in the Schedule 1 system-wide rate.

These changes are effective February 1, 2012.



January 25, 2012:

Rate changes were processed to incorporate the January Updates of Attachments O / GG / MM for the projected test year Transmission Owners. Recovery of MVP revenue requirements under Sch. 26-A begins on 1/1/12. MEC was approved to begin utilizing a projected test year effective 1/1/12 (Docket ER12-242). MRES was approved to begin utilizing a projected test year effective 1/1/12 (Docket ER12-351). Duke – Ohio (DEO) and Duke – Kentucky (DEK) were removed from MISO effective 1/1/12. Schedule 38 is being utilized beginning on 1/1/12 for the recovery of DEO’s MTEP obligations (Docket ER12-334). The phase-out of Pella’s impacts on transmission rates (as a result of their sale of Walter Scott – 4 transmission facilities) begins on 1/1/12 (Docket EC11-123). Hutchinson Utilities was added as a Transmission Owner in the GRE Pricing Zone effective 1/1/12. These actions resulted in changes to Schedules 1, 2, 7, 8, 9, 26, 26-A, 37, and 38 for Midwest ISO; in addition to all of the Interface Rates.

Overall, the impact on the Midwest ISO system rate is an increase of 4.40% for Schedules 7, 8 and 9; and an increase of 32.35% for Schedule 26.

RRI Energy Services (NERC ID – RES) merged with Mirant/Genon (NERC ID – MET). Mirant/Genon will receive the Schedule 2 Reactive Power payments previously received by RRI Energy Services effective 1/1/12. There are no impacts to the Schedule 2 rates from this transaction. The divisor for the Schedule 2 rate calculation was also updated as part of the January Attachment O update for projected test year Transmission Owners.

The overall impact of the rate revision was an increase of 0.93%.

These changes are effective January 1, 2012.



July 22, 2011:

Rate changes were processed to incorporate the impact of a correction to the SMMPA Attachment O divisor. The incorrect divisor was submitted to us during the June Updates of Attachment O / GG for the historical test year Transmission Owners. This action resulted in changes to Schedules 1, 2, 7, 8, 9, and 26/37 for Midwest ISO; in addition to all of the Interface Rates. A Billing Adjustment for the month of June, 2011 is also necessary, and is being worked on now for future implementation.

Overall, the impact on the Midwest ISO system rate is an increase of 0.004% for Schedules 7, 8 and 9; and an increase of 0.004% for Schedule 26/37.

Rate changes were made to Schedule 2 for the revenue requirement revisions approved for City, Water, Light, and Power (CWLP) and Dynegy Midwest Generation (DMG). The Commission’s July 1, 2011 Order in Docket No. EL11-31-000 accepted CWLP’s proposed revenue requirement for providing Reactive Supply and Voltage Control from Generation Sources Service (reactive power) effective 7/1/11. The Commission’s June 28, 2011 Order in Docket No. ER11-3528-000 accepted DMG’s revised revenue requirement for providing Reactive Supply and Voltage Control from Generation Sources Service (reactive power) effective 4/1/11. The divisor for the Schedule 2 rate calculation was also updated as part of the SMMPA Attachment O divisor correction. Billing adjustments for the April through June timeframe are being worked on now for future implementation.

The Midwest ISO average Schedule 2 rate decreased by 0.03%.

These changes are effective July 1, 2011.



June 21, 2011:

Rate changes were processed to incorporate the June Updates of Attachment O / GG for the historical test year Transmission Owners. ATSI was removed from MISO effective 6/1/11. MRES was added to the Otter Tail Power Pricing Zone effective 6/1/11. These actions resulted in changes to Schedules 1, 2, 7, 8, 9, and 26 for Midwest ISO; in addition to all of the Interface Rates.

Overall, the impact on the Midwest ISO system rate is an increase of 0.93% for Schedules 7, 8 and 9; and an increase of 9.87% for Schedule 26.

A rate change was made to Schedule 2 for the addition of Midland Cogeneration Venture (MCV) to the METC zone. The Commission’s May 31, 2011 Order in Docket No. ER11-3035-000 accepted MCV’s proposed rate schedule for Reactive Support and Voltage Control from Generation Sources Services effective 6/1/11. The Schedule 2 Resources in the ATSI Zone were removed from the Schedule 2 rate calculation consistent with ATSI’s departure from MISO effective 6/1/11. The divisor for the Schedule 2 rate calculation was also updated as part of the June Attachment O update for historical test year Transmission Owners.

The Midwest ISO average Schedule 2 rate increased by 5.78%.

These changes are effective June 1, 2011.



May 26, 2011:

A rate change was made to Schedule 2 for the addition of Prairie Power, Inc. (SOY) to the Ameren IL zone. The Commission’s April 12, 2011 Order in Docket No. EL11-16-000 accepted Prairie Power’s Reactive Power Revenue Requirement effective 5/1/11.

The Midwest ISO average Schedule 2 rate increased by 0.13%.

These changes are effective May 1, 2011.



February 25, 2011:

Rate changes were processed to incorporate the Order Accepting the Attachment O Filing of Ameren Transmission Company of Illinois (ATXI) in FERC Docket # ER11-2104. ATC also submitted a minor correction to their Attachment O True-Up, processed in January, 2011. Additionally, NWEC was added to the NSP Pricing Zone. These updates resulted in changes to Schedules 7, 8, and 9 for Midwest ISO; in addition to all of the Interface Rates.

Overall, the impact on the Midwest ISO system rate is an increase of 0.3% for Schedules 7, 8 and 9.

An update was also made to Schedule 2 for Manitowoc Public Utilities (MPU). The Commission’s February 1, 2011 Letter Order in Docket No. ER11-2422 accepted Manitowoc’s reduced Reactive Power Revenue Requirement effective 11/1/10.

The Midwest ISO average Schedule 2 rate decreased by 0.03%.

These changes are effective February 1, 2011.



January 28, 2011:

Rate changes were processed to incorporate the January Updates of Attachment O / GG for the approved forward-looking Transmission Owners (ATC, ITCM, METC, ITC, GRE, NSP, MP, Vectren, and OTP). These updates resulted in changes to Schedules 1, 2, 7, 8, 9, and 26 for Midwest ISO; in addition to all of the Interface Rates.

Overall, the impact on the Midwest ISO system rate is an increase of 0.9% for Schedules 7, 8 and 9; and an increase of 27.03% for Schedule 26.

An update was also made to Schedule 2 for Dairyland Power Cooperative (DPC). The Commission’s December 22, 2010 Letter Order in Docket No. ER11-1955 accepted DPC’s proposed Reactive Power Revenue Requirement effective 1/1/11.

The Midwest ISO average Schedule 2 rate increased by 0.3%.

These changes are effective January 1, 2011.



December 31, 2010:

Rate changes were processed to incorporate the additions of Big Rivers as a Transmission Owner (Docket # ER11-15), and Willmar as a 30.9 customer of Great Rivers Energy (Docket # ER10-3180). These updates resulted in changes to Schedules 1, 7, 8, 9, and 26 for Midwest ISO; in addition to all of the Interface Rates.

Overall, the impact on the Midwest ISO system rate is a decrease of 0.9% for Schedules 7, 8 and 9; and a decrease of 1.56% for Schedule 26.

An update was also made to Schedule 2 for Great Rivers Energy (GRE). The Commission’s November 24, 2010 Order in Docket No. EL10-87 accepted GRE’s proposed Reactive Power Revenue Requirement effective 12/1/10.

The Midwest ISO average Schedule 2 rate increased by 1.6%.

These changes are effective December 1, 2010.



September 28, 2010:

The only update in September resulted from the removal of the discount that has been applied to Schedule 7 and 8 rates for Point-to-Point Transmission service out of and through the Midwest ISO to sinks located in the MISO interface. We have provided 30 days notice of the pending discount removal by posting the notice on July 27, 2010.

This change will have no impact on the overall MISO system rate.

The removal of the MISO Interface discount will have no impact on already established rates.



August 25, 2010:

The only update in August resulted from the removal of the discount that has been applied to Schedule 7 and 8 rates for Point-to-Point Transmission service out of and through the Midwest ISO to sinks located in the MAPP interface. We have provided 30 days notice of the pending discount removal by posting the notice on July 1, 2010.

This change will have no impact on the overall MISO system rate.

The removal of the MAPP discount will have no impact on already established rates.



July 27, 2010:

Effective September 1, 2010, the discount that has been applied to rates for Point-to-Point Transmission Service out of and through the Midwest ISO to sinks located in the MISO interface will be removed. This means that effective September 1, 2010, the Midwest ISO Drive-Through and Out rates will apply. The current Midwest ISO Drive-Through and Out rates are noted below. These rates are subject to change.

	Firm 
	
		Daily On-Peak        $112.8460	     MW/Day 
		Daily Off-Peak       $80.3835	     MW/Day 
		Weekly               $564.2301	     MW/Week 
		Monthly              $2,444.9970      MW/Month 
		Yearly               $29,339.9644     MW/Year 

	Non-Firm 
	
		Hourly On-Peak       $7.0529          MW/Hour 
		Hourly Off-Peak      $3.3493          MW/Hour 
		Daily On-Peak        $112.8460        MW/Day 
		Daily Off-Peak       $80.3835         MW/Day 
		Weekly               $564.2301        MW/Week 
		Monthly              $2,444.9970      MW/Month 


July 01, 2010:

Effective August 1, 2010, the discount that has been applied to rates for Point-to-Point Transmission Service out of and through the Midwest ISO to sinks located in the MAPP interface will be removed. This means that effective August 1, 2010, the Midwest ISO Drive-Through and Out rates will apply. The current Midwest ISO Drive-Through and Out rates are noted below. These rates are subject to change.

	Firm 
	
		Daily On-Peak        $112.8460        MW/Day 
		Daily Off-Peak       $80.3835         MW/Day 
		Weekly               $564.2301        MW/Week 
		Monthly              $2,444.9970      MW/Month 
		Yearly               $29,339.9644     MW/Year 

	Non-Firm 
		
		Hourly On-Peak       $7.0529          MW/Hour 
		Hourly Off-Peak      $3.3493          MW/Hour 
		Daily On-Peak        $112.8460        MW/Day 
		Daily Off-Peak       $80.3835         MW/Day 
		Weekly               $564.2301        MW/Week 
		Monthly              $2,444.9970      MW/Month 


June 22, 2010:

The annual updates have been made for the Transmission Owners utilizing historical Attachment Os. These updates resulted in changes to Schedules 1, 7, 8, 9 and 26; in addition to the interface rates for SERC, IMO and SPP.

Overall, the impact on the MISO system rate is an increase of 4.22% for Schedules 7, 8 and 9; and an increase of 4.67% for Schedule 26.

Updates were also made to Schedule 2 as detailed below:

The Commission’s May 28, 2010 Letter Order in Docket No. ER10-978 approved Wolverine’s proposed Rate Schedule effective 6/1/10 for the Sumpter generation facility.

The Commission’s June 1, 2010 Letter Order in Docket No. EL10-35 approved an uncontested settlement regarding T.E.S. Filer City Station’s request to implement a revenue requirement for Reactive Supply and Voltage Control from Generation Sources Service.

The Commission’s May 26, 2010 Letter Order in Docket ER10-962 accepted a proposed Rate Schedule for twenty three generating units in the AmerenUE generation fleet, effective June 1, 2010.

The Midwest ISO average Schedule 2 rate increased by 13.3%.

Attached are the updated Schedules. Upon your review I will distribute the file to the appropriate parties.

These changes are effective June 1, 2010.



April 23, 2010:

Updates were made to Schedule 2 as detailed below:

The Commission’s March 9, 2010 Letter Order in Docket No. EC10-41 approved Wolverine’s acquisition of the Sumpter generation facility from FirstEnergy Generation Corporation. Due to the change of ownership of the Sumpter Power Station from First Energy to Wolverine, the NERC ID is being changed from FESC to WPSC.

An update was also made to GRE’s Sch. 2 Revenue Requirement

The Midwest ISO average Schedule 2 rate decreased by 1.76%.

Updates were also made to Schedules 7, 8, and 9 to include CMMPA Municipalities based on their 2007 Attachment O information. These updates also resulted in changes to the interface rates for SERC, IMO and SPP.

Overall, the impact on the MISO system rate is an increase of 0.03% for Schedules 7, 8 and 9.

These changes are effective April 1, 2010.



March 29, 2010:

Update NSP’s 2010 Attachment O divisor and the true-up amount for 2008 per Docket # ER10-541. These updates resulted in changes to Schedules 1, 2, 7, 8, 9 and 26; in addition to the interface rates for SERC, IMO and SPP.

Overall, the impact on the MISO system rate is an increase of 0.32% for Schedules 7, 8 and 9; and an increase of 1.38% for Schedule 26.

These rates are effective January 1, 2010.

In addition, updates were made to Schedule 2 as detailed below:

The Commission’s February 19, 2010 Letter Order in Docket No. ER10-455 accepted Ameren Energy Resources Generating Company’s (AERG) and Ameren Energy Generating Company’s (AEG) revised Schedule 2 revenue requirements. AERG’s revenue requirement reflects an increase from $1,038,378 to $2,004,650. AEG’s revenue requirement reflects an increase from $4,361,622 to $7,379,065.

The Schedule 2 rates are effective March 1, 2010.

The Midwest ISO average Schedule 2 rate increased by 3.26%.



January 29, 2010:

The annual updates have been made for the Transmission Owners utilizing forward looking Attachment Os. These updates resulted in changes to Schedules 1, 2, 7, 8, 9 and 26; in addition to the interface rates for SERC, IMO and SPP.

Overall, the impact on the MISO system rate is an increase of 6.54% for Schedules 7, 8 and 9; and an increase of 35.55% for Schedule 26. The large rate increase for Schedule 26 is not unexpected and is due to the construction of RECB projects.

In addition, updates were made to Schedule 2 as detailed below:

In the Commission’s January 12, 2010 Letter Order Docket No. ER10-325, the Commission accepted for filing Dynergy Midwest Generation’s (DMG) revised Rate Schedule FERC No. 5 “Reactive Supply and Voltage Control from Generation Sources Service.” In this case, the Reactive Service Revenue Requirement reflects a rate decrease from $3,980,731 to $3,199,348.

In the Commission’s January 14, 2010 Letter Order in Docket No. EL10-16, the Commission accepted Manitowoc Public Utilities’ (MPU) proposed revisions to Rate Schedule FERC No. 2. The Commission accepted the revisions as MPU proposed to revise the stated revenue requirements to reflect the retirement of MPU’s Diesel 1 Unit. Therefore MPU’s Reactive Service Revenue Requirement results in a reduction of the annual revenue requirement to $256,828.

In the Commission’s January 12, 2010 Letter Order in Docket No. ER10-323, the Commission accepted Tilton Energy LLC’s FERC Rate Schedule No. 1 for “Reactive Supply and Voltage Control from Generation Sources Service.” Tilton’s annual revenue requirement is $781,383 and was deemed as a Qualified Generator under Schedule 2 by the Midwest ISO.

The rates are effective January 1, 2010.



December 30, 2009:

This update was made to incorporate Montezuma, Tipton, Eldridge, and Pella into the MidAmerican Energy Company (MEC), pricing zone. Schedules 7, 8 and 9 were updated to reflect these utilities being implemented into the December 2009 rates.

The Commission’s November 20, 2009 letter order in ER09-1637 accepted the Midwest ISO and Tipton Municipal Utilities’ (Tipton) proposed revisions to Attachment O of the Midwest ISO Open Access Transmission, Energy, and Operating Reserve Markets Tariff. The revisions will allow Tipton to recover its share of zonal revenues related to its ownership interest in certain jointly-owned transmission facilities within MidAmerican’s pricing zone.

Also, the Commission’s November 20, 2009 Letter Order in Docket No. ER09-1636-000 and ER09-1636-001 accepted the Midwest ISO’s and Montezuma Municipal Light and Power’s (Montezuma) proposed revisions to Attachment O of the Midwest ISO Open Access Transmission, Energy, and Operating Reserve Markets Tariff. The revisions will allow Montezuma to recover its share of zonal revenues related to its ownership interest in certain jointly-owned transmission facilities within MidAmerican’s pricing zone.

The rates are effective December 1, 2009.

These changes affected the MEC pricing zone rate increasing it 0.60% from the November rates. Also, the MISO average rate increased 0.02% as a result of the changes.



November 30, 2009:

Schedule 2 changes:

Since the last rate update to Schedule 2 in September 2009 the above changes increased the monthly MISO average Schedule 2 rate by 1.26% and increased the ALTE Zone rate by 57.63%.

As stated above, the updated rates are effective June 1, 2009.



September 30, 2009:

This update is being made to incorporate the Iowa utilities of MidAmerican and Muscatine into the Transmission and Ancillary Services rate schedules. Overall, the impact on the MISO system rate is a decrease of 0.68% for Schedules 7 and 8. Rates and changes are effective September 1, 2009. Schedules 1, 2 and 9 have also been updated to account for the addition of MEC and MPW. The Price by Sink rates for these two entities have also been updated.



August 31, 2009:

The Schedule 2 changes decreased the monthly MISO average Schedule 2 rate by 1.57%, decreased the AMIL zone rate by 14.33%.

Rates and changes are effective 8/1/09.



July 31, 2009:

Updates have been made to Schedules 1, 2, 7, 8, 9 and 26; in addition to the interface rate for MISO and are summarized below:

Rates and changes are effective as stated above.

The overall impact of the MISO system rate is a less than 1% change for Schedules 7, 8, 9, & 26.



June 29, 2009:

ITC and METC discovered that expenses related to account 561.BA were being recovered through Schedule 1 and should not have been. This rates change reflects the removal of $951,180 and $632,269, respectively for ITC and METC from Schedule 1.

Overall, the impact on the MISO system rate is a decrease of 2.70% for Schedule 1. These rates are effective June 1, 2009.



June 17, 2009:

Overall, the impact on the MISO system rate is an increase of 4.82% for Schedules 7, 8, and 9; and an increase of 12.71% for Schedule 26.

Rates and changes are effective June 1, 2009.

There were no changes to the MHEB rates.



May 29, 2009:

On December 9, 2008 Ameren Energy Marketing Company filed proposed rate schedules regarding revenue requirements for reactive power (Schedule 2) supplied by eight generating units in the Ameren Marketing fleets to the Midwest ISO. On April 3, 2009, per the order ER09-398-000, FERC accepted Ameren Marketing’s proposed rate schedules, suspending them for a nominal period to be effective on the date requested of May 1, 2009, subject to refund. Therefore, the Schedule 2 rates were updated effective May 1, 2009. This update increased the overall Schedule 2 MISO rate by approximately 5%.



April 29, 2009:

No Schedule rate changes occurred for April 2009. The Price by Sink tab has been updated to reflect the move of LES, NPPD and OPPD from MAPP to SPP.

MHEB Schedule rates can now be viewed on the MHEB OASIS and historical archiving for 4/1/09 forward will be available there. Historical MHEB rates prior to 4/1/09 will still be accessible on the MISO OASIS page



February 28, 2009:

The rates for Schedules 3, 5, & 6 were set to zero effective 2/1/09 due to the 1/6/09 implementation of the ASM market under which Schedules 3, 5, & 6 became market-based rates. Tariff Pricing kept Schedules 3, 5, & 6 active through the ASM reversion period of 2/6/09. The Midwest ISO settled the entire month of January 2009 using the previously existing rates for Ancillary Services 3, 5 and 6. There will be a prorated adjustment in the February Settlement run to account for ASM implementation on January 6th, 2009.



January 30, 2009:

The attached files are for the January 2009 rate update.

The attached files are the revised January 2009 rate updates. The annual updates have been made for the Transmission Owners utilizing forward looking Attachment Os. These updates resulted in changes to Schedules 1, 2, 7, 8, 9 and 26.

Overall, the impact on the MISO system rate is an increase of 8.50% for Schedules 7, 8, and 9; and an increase of 91.60% for Schedule 26. The large rate increase for Schedule 26 is due to the construction of RECB projects. Also, starting in January Pricing Zone 13A (Michigan Joint Sub Zone) has been added for the first time in Schedule 26.

Rates and changes are effective January 1, 2009.



December 19, 2008:

The attached files are for the December 2008 rate update.

The attached revised rates reflect the December 12, 2008 Commission approval of Invenergy’s reactive power revenue requirement request (ER08-1333). As a result, effective December 1, 2008, Schedule 2 was revised to reflect the Commission approved revenue requirement for Invenergy’s Cannon Falls facility in the NSP zone. This change also affected the Midwest ISO Schedule 2 through and out rate.

Overall, the impact to the MISO system average rate is an increase of 4.4%.

Rates and changes are effective December 1, 2008.



November 25, 2008:

The attached revised rates reflect the April 17, 2008 Commission approval of the Coordination Agreement between the Midwest ISO and Manitoba Hydro (Dockets ER08-592and ER-1177). As a result, effective November 1, 2008, Manitoba Hydro was removed from the Midwest ISO average through and out rates. In addition, the new rates for Schedules 3, 5 and 6 are now zero for Manitoba Hydro. This update resulted in changes to Schedules 1, 2, 3, 5, 6, 7 and 8. In addition the attached revised rates reflect the November 12, 2008 FERC approval of the Capacity Benefit Margin (CBM) adjustment to the Midwest ISO average through and out rate for Schedules 7 and 8 (Docket OA08-4).

The Pricing by Sink tab reflects these changes.

Rates and changes are effective November 1, 2008.



July 30, 2008:

Schedule 2 rates were revised. This affects only the Schedule 2 METC rate and the Midwest ISO system average rate.

Rates and changes are effective July 1, 2008.



July 1, 2008:

Annual updates have been made for the Transmission Owners utilizing historical Attachment O information. These updates resulted in changes to Schedules 1, 2, 7, 8, 9, and 26. Ameren Illinois, Manitoba Hydro and Detroit Edison submitted revised rates for Schedules 3, 5, and 6. The interface rates for SERC, SPP, and IMO have been updated to reflect the changes to Schedules 7 and 8.

Rates and changes are effective June 1, 2008.

The Pricing by Sink tab reflects these changes.



April 29, 2008:

Rates in Schedules 3 and 5 are updated to reflect Ameren Illinois most current rates. The rates are effective April 1, 2008.



March 31, 2008:

Rates in Schedule 2 are updated to reflect the implementation of interim settlement rates per the FERC's January 31, 2008 Order in ER07-770. Rates are effective March 1, 2008. The Pricing by Sink tab reflects these changes.



March 6, 2008:

Effective March 1, 2008, the rates for point-to-point transmission service out of and through the Midwest ISO to the MAPP and MISO interfaces will change to the rates stated below.

The revised rates for MAPP are as follows:

	Firm 

            Daily On-Peak         $53.1328            MW/Day 
            Daily Off-Peak        $37.9520            MW/Day 
            Weekly               $265.6638            MW/Week 
            Monthly            $1,151.2097            MW/Month 
            Yearly            $13,814.5164            MW/Year 

	Non-Firm

            Hourly On-Peak         $1.0000            MW/Hour 
            Hourly Off-Peak        $0.5000            MW/Hour 
            Daily On-Peak         $16.0000            MW/Day 
            Daily Off-Peak        $12.0000            MW/Day 
            Weekly               $265.6638            MW/Week 
            Monthly            $1,151.2097            MW/Month 


The revised rates for MISO are as follows:

	Firm 

            Daily On-Peak         $53.1328            MW/Day 
            Daily Off-Peak        $37.9520            MW/Day 
            Weekly               $265.6638            MW/Week 
            Monthly            $1,151.2097            MW/Month 
            Yearly            $13,814.5164            MW/Year 

	Non-Firm

            Hourly On-Peak         $3.5000            MW/Hour 
            Hourly Off-Peak        $1.7500            MW/Hour 
            Daily On-Peak         $48.0000            MW/Day 
            Daily Off-Peak        $36.0000            MW/Day 
            Weekly               $265.6638            MW/Week 
            Monthly            $1,151.2097            MW/Month 


February 29, 2008:

Rates in Schedules 2, 7, 8, and 9 are updated to reflect minor changes in the Michigan Joint Subzone entitlement usage. Rates are effective February 1, 2008. The Pricing by Sink tab reflects these changes.



February 29, 2008:

The Regional Through and Out Rates (RTOR) reflected on the “Pricing by Sink” tab on the Oasis site, will be revised to reflect the February 1, 2008 sunset of Schedule 14. In the past the rates on the “Pricing by Sink” tab were a combination of Schedules 7 or 8 and Schedule 14.

Prospectively, these rates will be as follows:

The revised rates for MAPP are as follows:

	Firm 
 
            Daily On-Peak         $38.8013            MW/Day 
            Daily Off-Peak        $27.6118            MW/Day 
            Weekly               $194.0067            MW/Week 
            Monthly              $840.6956            MW/Month 
            Yearly            $10,088.3467            MW/Year 

	Non-Firm

            Hourly On-Peak         $0.7303            MW/Hour 
            Hourly Off-Peak        $0.3649            MW/Hour 
            Daily On-Peak         $11.6843            MW/Day 
            Daily Off-Peak         $8.7306            MW/Day 
            Weekly               $194.0067            MW/Week 
            Monthly              $840.6956            MW/Month 

The revised rates for MISO are as follows:

	Firm 
 
            Daily On-Peak         $38.8013            MW/Day 
            Daily Off-Peak        $27.6118            MW/Day 
            Weekly               $194.0067            MW/Week 
            Monthly              $840.6956            MW/Month 
            Yearly            $10,088.3467            MW/Year 
 
	Non-Firm
 
            Hourly On-Peak         $2.5560            MW/Hour
            Hourly Off-Peak        $1.2770            MW/Hour 
            Daily On-Peak         $35.0530            MW/Day 
            Daily Off-Peak        $26.1917            MW/Day 
            Weekly               $194.0067            MW/Week
            Monthly              $840.6956            MW/Month


February 19, 2008:

Rates in Schedules 1, 2, 7, 8, 9, and 26 are updated to reflect the annual update of the Attachment O's of Transmission Owners utilizing the forward looking method. Additionally, ALTW's/ITCM's divisor was updated. The Pricing by Sink tab reflects these changes.



February 1, 2008:

Effective February 1, 2008 the discount that has been applied to rates for point-to-point transmission service out of and through the Midwest ISO to the Southeast Region (SERC and FPCC) has been removed.



February 1, 2008:

As a result of the expiration of the six year Transition Period, effective February 1, 2008 Schedule 14, the Regional Through and Out (RTOR) charge, will sunset in accordance with the tariff.



February 1, 2008:

As a result of the sunset of Schedule 14, effective February 1, 2008, the Regional Through and Out (RTOR) rates for MAPP and MISO have been revised to reflect the sunset of Schedule 14

The revised rates for MAPP are as follows:

	Firm 

            Daily On-Peak         $34.4035            MW/Day 
            Daily Off-Peak        $24.5739            MW/Day 
            Weekly               $172.0173            MW/Week 
            Monthly              $745.4083            MW/Month 
            Yearly             $8,944.8994            MW/Year 

	Non-Firm

            Hourly On-Peak         $0.6475            MW/Hour 
            Hourly Off-Peak        $0.3238            MW/Hour 
            Daily On-Peak         $10.3600            MW/Day 
            Daily Off-Peak         $7.7700            MW/Day 
            Weekly               $172.0173            MW/Week 
            Monthly              $745.4083            MW/Month 

The revised rates for MISO are as follows:

	Firm 

            Daily On-Peak         $34.4035            MW/Day 
            Daily Off-Peak        $24.5739            MW/Day 
            Weekly               $172.0173            MW/Week 
            Monthly              $745.4083            MW/Month 
            Yearly             $8,944.8994            MW/Year 

	Non-Firm

            Hourly On-Peak         $2.2663            MW/Hour 
            Hourly Off-Peak        $1.1331            MW/Hour 
            Daily On-Peak         $31.0800            MW/Day 
            Daily Off-Peak        $23.3100            MW/Day 
            Weekly               $172.0173            MW/Week		
	    Monthly              $745.4083            MW/Month 


December 31, 2007:

Rates in Schedule 2 are updated to reflect changes for Reliant and Dynegy. Additionally the Michigan Joint Zone Sub zone was added to Schedules 7, 8, and 9. These changes are effective December 1, 2007. The Pricing by Sink tab reflects these changes.



December 03, 2007:

Rates in Schedules 2, 7, 8, 9 and 26 are updated to reflect changes in the Attachment O divisor and revenue requirement. The Pricing by Sink tab reflects these changes.



October 31, 2007:

Rates in Schedules 7, 8 and 9 are updated. Overall the impact to the Midwest ISO system wide rate is an increase of 0.56% in Schedules 7 and 8. The Pricing by Sink tab reflects these changes.



September 4, 2007:

Rates in Schedules 2 are updated effective August 1, 2007.



August 6, 2007:

Rates in Schedules 1, 2, 7, 8, 9, and 26 are updated to reflect a load update. Rates are effective June 1, 2007. The Pricing by Sink tab reflects these changes.



July 9, 2007:

The price changes affect Schedules 1, 2, 3, 5, 6, 7, 8, 9, and 26, effective June 1, 2007. The Pricing by Sink tab reflects these changes.



June 1, 2007:

Price changes affect schedules 1, 2, 3, 5, 6, 7, 8 and 9.



May 1, 2007:

Effective June 1, 2007 the discounted rates for point-to-point transmission service out of and through the Midwest ISO to the Southwest Power Pool (SPP) have been removed.

Also, effective June 1, 2007 the rates for point-to-point transmission service out of and through the Midwest ISO to the southeast region interfaces, (e.g. SERC and FPCC) will change to the rates stated below for a minimum of sixty (60) days.

	Firm 
 
            Daily On-Peak         $84.9469            MW/Day 
            Daily Off-Peak        $60.8192            MW/Day 
            Weekly               $424.7345            MW/Week 
            Monthly             $1840.5161            MW/Month 
            Yearly             $22086.1936            MW/Year 
 
	Non-Firm
 
            Hourly On-Peak         $5.3988            MW/Hour 
            Hourly Off-Peak        $2.6125            MW/Hour 
            Daily On-Peak         $82.3805            MW/Day 
            Daily Off-Peak        $53.8432            MW/Day 
            Weekly               $424.7345            MW/Week 
            Monthly             $1840.5161            MW/Month 


May 1, 2007:

This Schedule 26 adjustment does NOT affect the Schedule 26 through and out rate nor does it affect Schedules 1, 2, 3, 5, 6, 7, 8, 9, and 14.



April 2, 2007:

Attachment O needed to be adjusted to account for Schedule 26 revenue requirements. Price changes affect Schedules 7, 8, and 9 and do not impact ancillary services. The Pricing by Sink tab reflects these changes.



March 27, 2007:

A Schedule 26 tab (Network Upgrade Charges as a result of MTEP 06) will now be included in the pricing spreadsheet posted on the Midwest ISO OASIS.



March 22, 2007:

Price changes affect Schedule 2 only and are a result of adding the Mankato Generator in the NSP pricing zone. Rates are effective March 1, 2007.

February 8, 2007:

Price changes affect Schedules 1, 2, 7, 8, and 9 and are a result of ATC reducing their load forecast. Rates and changes are effective January 1, 2007. The Pricing by Sink tab reflects these changes.



January 30, 2007:

Rate changes for Schedules 7, 8, and 9, which are effective January 1, 2007, are a result of annual forward looking cost recovery updates from ATC and ITC. Ancillary Services schedules were not affected with these rate changes. The Pricing by Sink tab reflects these changes.



January 29, 2007:

The Midwest ISO has reviewed rates for Non-Firm Hourly and Daily Transmission Service to those sinks in the Southwest Power Pool formerly having access to MAPP Schedule F and will be changing these rates to match the current rates to the other sinks in the Southwest Power Pool. The prices for drive-out and drive-through Transmission Service to the Midwest ISO’s interface with the Southwest Power Pool will change effective March 1, 2007. The new rates for Non-Firm Hourly and Daily Transmission Service affect the following sinks: KACY, KCPL, MPS, SJLP, and WPEK.



January 25, 2007:

Price updates affect Ancillary Services, resulting from updating ATC's forward looking costs and the addition of Manitowoc Public Utilities providing reactive power under ATC's WPS zone. Rates are effective January 1, 2007.



January 16, 2007:

Price updates affect Ancillary Services. Rates are effective January 1, 2007. The price change for Schedules 3 and 5 resulted from Ameren updating allocation factors.



December 26, 2006:

Rate changes are effective January 1, 2007 for the Ameren BA consolidation. Schedule 2 Average through and out rates decreased for the On Peak Hourly rate. Schedules 7, 8, and 9 had an increase in the MISO System average rate.



December 1, 2006:

Rates have changed for Schedules 2, 7, 8, and 9. Schedule 2 changes are a result of a FERC Order reducing a revenue requirement at the Dearborn Industrial Generation plant. Schedules 7, 8, and 9 changed due to 1.a FERC Order on SMMPA, 2.correcting an error in data submitted to MISO for NSP, and 3.correcting an error in data submitted to MISO for Ameren IP.



November 7, 2006:

Schedule 2 rates are updated to reflect the addition of the Endicott generator in Michigan. The FERC order made this effective October 1, 2006. No other schedules are affected by this change.



October 31, 2006:

Effective December 1, 2006 the rates for point-to-point transmission service out of and through the Midwest ISO to the Southwest Power Pool will change to the rates stated below for a minimum of sixty (60) days. The rates for non-firm hourly and daily transmission service to those non-MISO member MAPP entities will remain unchanged.

	Firm 

		Daily On-Peak           $94.1639    	MW/Day 
		Daily Off-Peak          $67.4504    	MW/Day 
		Weekly                  $470.8196   	MW/Week 
		Monthly                 $2040.2182  	MW/Month 
		Yearly                  $24482.6180 	MW/Year 

	Non-Firm 

		Hourly On-Peak          $5.9450     	MW/Hour 
		Hourly Off-Peak         $2.8587     	MW/Hour 
		Daily On-Peak           $92.4530    	MW/Day 
		Daily Off-Peak          $66.7997    	MW/Day 
		Weekly                  $470.8196   	MW/Week 
		Monthly                 $2040.2182  	MW/Month 


October 30, 2006:

Schedule 2 rates are updated reflecting a decrease in the through and out rate as well as the ITC zone rates. No other schedules are affected by this change.



October 10, 2006:

Schedule 2 rates have changed in the Michigan Joint Zone with the addition of the New Covert Generator. The rates provided reflect LGEE's departure. Only Schedule 2 rates are affected.



September 1, 2006:

With LGEE leaving the Midwest ISO, Attachment O calculations have changed transmission service rates effective September 1, 2006. Schedule 1 (Dispatch) rates increased since LGEE had higher revenue credits than Acct 561, Schedule 2 the MISO rate was affected with a slight increase, Schedule 3 (Regulation) change is due to ITC decreasing rates, Schedule 5 (Spinning Reserve) change is due to ITC decreasing rates, Schedule 6 (Operating Reserve) change is due to ITC decreasing rates, Schedule 7 (Firm PTP) the MISO wide rate increased, Schedule 8 (Non Firm PTP) the MISO wide rate increased. The Pricing by Sink tab reflects these changes.



August 2, 2006:

Effective September 1, 2006 all out and through Transmission Service sinking in LGEE will be priced the same as other MISO 1st tier interconnections, excluding PJM members, directly interconnected to LGEE (BREC, OVEC, EEI, and EKPC).

Effective September 1, 2006 the rates are as follows:

                                           FIRM

$/MW-Day                $/MW-Day                $/MW-Week       $/MW-Month       $/MW-Yearly
Daily On Peak           Daily Off Peak          Weekly          Monthly           Yearly
-----------------	------------------	----------	--------------	  -----------
$53.1328		$37.9520		$265.6638	$1,151.2097	  $13,814.5164

                                          NON FIRM

$/MWh			$/MWh		$/MW- Day	$/MW- Day	$/MW- Week     $/MW Month
Hrly On Peak	 	Hrly Off Peak	Daily On Peak	Daily Off Peak  Weekly	       Monthly	
-----------------	--------------  ------------	--------------	-----------    --------------
$3.5000			$1.7500		$48.0000	$36.0000	$265.6638      $1,151.2097


July 26, 2006:

FERC has approved ATSI's Vegetation Management Program. Rates have decreased in ATSI for Schedules 7, 8 and 9. The Midwest ISO system-wide average rate for transmission service also changes. The Pricing by Sink tab reflects these changes.



July 5, 2006:

Schedule 2 rates change effective July 1, 2006 due to a settlement in Docket No ER05-1050. The overall Schedule 2 rates decreased approximately 3.7% with IP decreasing around 43%. Other Ancillary Services schedules were not affected.



June 26, 2006:

Effective June 1, 2006, An updated Attachment O has changed the rates in Schedules 7, 8, and 9 in the Michigan Pricing Zone. System rates in Schedules 7 and 8 have changed as well. The Pricing by Sink tab reflects these changes.



June 1, 2006:

Annual Attachment O calculations are changing transmission service rates effective June 1, 2006. ATC pricing zone rate do not change. Schedules 1 & 2 Midwest ISO System Wide Rates change effective June 1, 2006. Schedule 2 rates for many pricing zones (but not all) change as a result of the Attachment O load data. Schedule 2 has a new service provider, DTE East China, in the ITC pricing zone. Manitoba Hydro reduced the price of Ancillary Service Schedules 2, 3, 5 & 6.



June 1, 2006:

Effective July 1, 2006 the rates for point-to-point transmission service out of and through the Midwest ISO to the Southwest Power Pool will change to the rates stated below for a minimum of sixty (60) days. The rates for non-firm hourly and daily transmission service to those non-MISO member MAPP entities will remain unchanged.

	Firm 

		Daily On-Peak           $73.6484    	MW/Day 
		Daily Off-Peak          $52.7012    	MW/Day 
		Weekly                  $368.2417   	MW/Week 
		Monthly                 $1595.7139  	MW/Month 
		Yearly                  $19148.5672 	MW/Year 

	Non-Firm 

		Hourly On-Peak          $4.7225     	MW/Hour 
		Hourly Off-Peak         $2.3044     	MW/Hour 
		Daily On-Peak           $70.2265    	MW/Day 
		Daily Off-Peak          $51.3999    	MW/Day 
		Weekly                  $368.2417   	MW/Week 
		Monthly                 $1595.7139  	MW/Month 


March 30, 2006:

SMMPA is a new zone effective April 1, 2006 for transmission and ancillary pricing. Because SMMPA has load in other pricing zones, the rates for GRE, ALTW and NSP increase. ATSI has a rate increase for service at 138 kV and above effective April 1, 2006. The Midwest ISO System Average Rate for Drive Through/Drive Out increases. Schedule 1 rates increase with the addition of SMMPA. Schedule 2 system-wide rate decrease. The transition period for SECA rates expires March 31, 2006. The Schedule 22 rates tab has therefore been removed from from the Transmission Pricing by Sink spreadsheet. The Pricing by Sink tab reflects these changes.



Febuary 03, 2006:

The price change is the result of the ATC annual recalculation of transmission rates. The previously posted rates (eff 1-1-06) by design included some preliminary data. The data is final and the rate can be finalized. The change in posted ATC Schedules 7, 8 & 9 rates is a slight decrease (from those presently posted eff 1-1-06). However, customers will see the rates increase over the Dec 2005 effective rates. Midwest ISO system-wide rates for Schedules 7 & 8 decrease for those customers paying full price. ATC-WEC Schedule 2 decreases. Midwest ISO Schedule 1 decreases. Midwest ISO Schedule 2 decreases. The Pricing by Sink tab reflects these changes.



January 06, 2006:

Schedules 7, 8 & 9 rates in the Michigan Joint Zone decrease effective Jan 1, 2006. There is a corresponding decrease in the Midwest ISO system-wide average rate. Schedule 2 rates in the ITC pricing zone increase effective Jan 1, 2006. There is a corresponding increase in the Midwest ISO system-wide rate. The Pricing by Sink tab reflects these changes.



December 27, 2005:

Six zones are changing transmission rates effective Jan 1, 2006: ATC (5 zones) annual rate calculation and Michigan Joint Zone (old METC zone). The Midwest ISO system-wide average rate for transmission service also increases. Schedule 1 rate changes in two ways: The Michigan Joint Zone Schedule 1 rate ends Dec 31, 2005 and the Midwest ISO system-wide rate decreases. Schedule 2 rates decrease for ATC-WEC, Michigan Joint Zone, and Midwest ISO system-wide rate. The Pricing by Sink tab reflects these changes.



December 2, 2005:

Effective Dec 1, 2005 the Schedule 2 rate for the ITC pricing zone decreases. There is a corresponding decrease in the Midwest ISO system average rate under Schedule 2. The change is required to correct an error in the Detroit Edison revenue requirement calculation.



November 23, 2005:

There is a new Schedule 2 recently approved by the Commission. This change allows Independent Power Producers with approved tariffs to receive revenue from the Midwest ISO. The change is effective Dec 1, 2005.



October 27, 2005:

MHEB prices for Schedules 2, 3, 5, & 6 increase effective November 1, 2005. System wide rate for the Midwest ISO Schedule 2 is also affected.



October 3, 2005:

The two year transition period for zonal and subzonal pricing under Schedules 18 & 19 ends effective October 1, 2005. These two schedules are generally known as SRA and ZTA. Ancillary service prices are not affected. The Pricing by Sink tab reflects this change.



August 24, 2005:

Effective August 1, 2005, Missouri Joint Municipal Electric Utility Commission and select members are a separate subzone in the Ameren pricing zone. The Pricing by Sink tab reflects this change.



July 15, 2005:

DTE increased the price charged for Schedule 2, Reactive Power, in the ITC pricing zone. The change incorporates the Commission approved revenue requirement for First Energy Solutions' Sumpter plant. Price increase is effective July 1, 2005. Midwest ISO System Wide Average rate for Schedule 2 also increases.



July 8, 2005:

Transmission service rates are recalculated annually, effective June 1.



May 31, 2005:

Effective May 1, 2005 ATC LLC prices for Transmission Service are now the same across each of its five pricing zones. The Midwest ISO System-Wide Average Rate also increases. Midwest ISO System-Wide Average Rates for Schedules 1 & 2 are slightly higher. Effective May 1, 2005, the Schedule 7, 8, and 14 through and out rates on reservations sinking in VAP are reduced to zero per FERC Order. The Pricing by Sink tab reflects these changes.

May 02, 2005:

Schedule 2 rates for ATSI and METC have been reduced by Commission order. The Midwest ISO System-Wide Average Rate is also reduced. Refunds for service prior to April 1, 2005 are being processed (Aug 1, 2004 for ATSI and Sept 1, 2004 for METC). Schedule 22 rates are now included within the Transmission Pricing by Sink spreadsheet.



February 04, 2005:

Effective February 1, 2005 the American Transmission System, Inc. pricing zone rates increase as the company's rate designs change to comply with Attachment O from the OATT. Midwest ISO Schedules 1 & 2 System-Wide Average rates increase. Midwest ISO Schedules 7 & 8 System-Wide Average rates increase, but the increase has no affect on discounted prices under these schedules. The Pricing by Sink tab reflects these changes.



January 28, 2005:

Effective February 1, 2005, rates in the NIPSCo pricing zone change. The Midwest ISO System-Wide Average rate for Schedules 7 & 8 increase. The Midwest ISO System-Wide Average rates under Schedules 1 & 2 increase also. Ancillary Service rates for NIPSCo are unaffected. Also effective February 1, 2005, the discounted rate for the IMO Sink has been removed. The Pricing by Sink tab reflects these changes.



January 10, 2005:

Effective January 1, 2005, the Schedule 7, 8, and 14 through and out rates on reservations sinking in DLCO are reduced to zero per FERC Order. Also, prices in the ITC pricing zone for Schedules 7, 8 & 9 changed effective Jan 1, 2005. This causes the price to increase for the Midwest ISO System-Wide Average Rate for Schedules 7, 8 & 9. The Pricing by Sink tab reflects these changes. No ancillary service prices are affected.



December 21, 2004:

Effective December 1, 2004, the Schedule 7, 8, and 14 through and out rates on reservations sinking in AP are reduced to zero per FERC Order. The Pricing by Sink tab reflects this change.



December 15, 2004:

December 15, 2004: Effective December 1, 2004, Great River Energy is a MISO Transmission Owner and pricing zone. The addition of GRE changes the rates for GRE, ALTW, NSP, MP and OTP. Midwest ISO System Average Rates change for Schedules 1, 2, 7 & 8. Also effective December 1, 2004, the Schedule 7, 8, and 14 through and out rates on reservations sinking in PJM, CE, DPL and AEP are reduced to zero per FERC order. The pricing by sink tab reflects this change.



December 15, 2004:

December 15, 2004: This rate file, dated October 15, 2004 is posted to reflect a correction to Ameren rates in Schedules 7, 8, and 9. The rate correction is effective Oct 1, 2004. No other rates are effected by this change. The addition of this excel spreadsheet is done for continuity purposes only as actual charges have been calculated using these corrected rates as of October 1, 2004.



Septemner 30, 2004:

Effective October 1, 2004, Illinois Power is an effective pricing zone. Also, Ameren implements formula rates in accordance with Midwest ISO OATT Attachment O. Associated decreases in Midwest ISO Schedules 1 & 2 occur.



Septemner 6, 2004:

September 6, 2004: Effective September 1, 2004, there is a price change for METC Schedule 2. As a consequence, the Midwest ISO Schedule 2 price also changed. No other pricing changes are included in these files. This September 1, 2004 rate update does not impact the current discounted drive through/out rates for service requested after 7/1/02.



August 5, 2004:

Effective August 1, 2004, City of Columbia, Missouri is a MISO pricing zone. CWLD zonal rates have been changed to the CWLD formula rates. Effective August 1, 2004 there is a price increase in Schedule 2 for ATSI. The Midwest ISO Schedule 1 rate is reduced. The Midwest ISO Schedule 2 rate is increased. The formula Midwest ISO system-wide average rate for drive through/out service has increased. This August 1, 2004 rate update does not impact the current discounted drive through/out rates for service requested after 7/1/02.



July 20, 2004:

Effective July 1, 2004, rates under schedules 2, 3, 5, and 6 for ITC have been reduced. Midwest ISO Schedule 2 is also affected.
Effective May 1, 2004, Point-to-Point rates to the sink of CWLD are discounted.



June 16, 2004:

This rate posting corrects HE Schedule 7 zonal rates. All other rates are as posted on May 28, 2004. This posting incorporates a "pricing by sink" tab. The June 1, 2004 rate update does not impact the current discounted through and out rates for service requested after 7/1/02.



May 28, 2004:

Effective June 1, 2004, rates under Schedules 7, 8 & 9 for all zones except for METC, ITC, ATC, Ameren, ATSI and NIPSCO have changed due to annual updates. Midwest ISO rates for Schedules 1 & 2 and all MHEB schedules are updated as well.



May 13, 2004:

Effective May 1, 2004 ATSI/FE Schedule 2 pricing will change. Consequently, the Midwest ISO system average rate for Schedule 2 also changed. No other pricing is affected. This rate update does not impact the current discounted through and out rates for service requested after 7/1/02.



April 21, 2004:

Effective May 1, 2004, Rates for transmission requests will change with the addition of the GridAmerica - Ameren pricing zone. The updated pricing reflects changes in Midwest ISO system average rates and new pricing for Schedules 18 & 19. This rate update does not impact the current discounted through and out rates for service requested after 7/1/02.



April 15, 2004:

As a result of settlement in FERC docket ER03-580, GridAmerica Schedule 9 rates and the Schedule 18 and 19 rates have been adjusted. These settlement-based rates are effective back to October 1, 2003. MISO Settlements will be making adjustments. Midwest ISO System Average Rates are not affected. This rate update does not impact the current discounted through-and-out rates for service requested after 7/01/02.



February 5, 2004:

Effective February 1, 2004, ATC LLC pricing zones have an adjustment in rates. This is the result of the FERC approved rate phase-in plan. Midwest ISO System Average Rates are affected: Schedules 1, 2, 7, 8 & 9. This rate update does not do not impact the current discounted through-and-out rates for service requested after 7/01/02.



January 29, 2004:

Effective January 1, 2004 ITC zonal pricing will change for ancillary services. As a result the Midwest ISO System Average rate for Schedule 2 has changed. There are no changes to any zonal rates for Schedules 7, 8 or 9.



December 31, 2003:

Updated the posted Transmission Service Rates to include the "Pricing by Sink" tab that lists the current discounted through-and-out rates. The ATC Zonal Price change effective January 1, 2004 does not impact the current discounted through-and-out rates.



December 23, 2003:

Effective January 1, 2004 ATC zonal pricing will change for Schedules 1, 7, 8 & 9. Midwest ISO system average rate also changes, along with Midwest ISO average rates for Schedules 1 & 2. ATC LLC changes rates effective January 1st in accordance with FERC approved rate phase-in plan.



November 26, 2003:

Effective December 1, 2003, Rates for MHEB Schedules 2, 3,5 & 6 and Midwest ISO Schedule 2 periodic updates.



October 6, 2003 Updated Pricing Files:

Effective October 1, 2003, Rates for transmission requests made after midnight on October 1, 2003 will change with the addition of ATSI and NIPSCo pricing zones and Schedules 18 & 19 (SRA & ZTA) and are now included in the Point Transmission Service Rates spreadsheet. Also effective October 1, 2003, MISO will modify selected on-peak and off-peak hourly RTOR rates. The updated hourly rates are reflected in the Point-to-Point Transmission Service Rates spreadsheet. The new pricing for the OASIS requests will appear on all OASIS requests following the billing process for September business.



September 29, 2003:

Effective October 1, 2003, Rates for transmission requests made after midnight on October 1, 2003 will change with the addition of ATSI and NIPSCo pricing zones and Schedules 18 & 19 (SRA & ZTA). Also effective October 1, 2003, MISO will modify selected on-peak and off-peak hourly RTOR rates. The updated hourly rates are reflected in the Point-to-Point Transmission Service Rates spreadsheet. The new pricing for the OASIS requests will appear on all OASIS requests following the billing process for September business.



June 25, 2003:

Effective 7/1/2003, the MISO will modify selected on-peak and off-peak hourly RTO Rates. The updated hourly rates are reflected in the Point to Point Transmission Service Rates spreadsheet.



June 4, 2003:

Effective June 1, 2003 all zones (including Midwest ISO) Schedules 7, 8 & 9 have changed due to annual updates. For ancillary services Schedule 2 rates for SIPC are new. Midwest ISO rates for Schedules 1 & 2 are new.



March 28, 2003:

Effective March 1, 2003 by FERC order International Transmission has new prices for Schedules 7, 8 & 9. This is due to completion of the asset divestiture by Detroit Edison. ITC prices are affected. The discount that was in effect from June 1, 2002 to date is replaced with a capped rate effective March 1. The difference between the cap rate and the discounted rate is rounding. The capped rate is slightly lower. Midwest ISO system average rate has gone down (Schedules 7 & 8).



March 1, 2003:

Schedules 2,3,5 & 6 have been updated. This does not change the Transmission Service rates currently in affect.



February 1, 2003:

Schedules 1, 2, 7, 8 & 9. ATC zonal prices are affected, as are Midwest ISO average rates. Zonal ancillary services are not affected. ATC LLC changes rates effective Feb 1 in accordance with FERC approved rate phase-in plan. This also changes Midwest ISO average rates for Through/Out service, but do not impact the current discounted through-and-out rates for service requested after 7/01/02.

January 1, 2003:

Schedules 1, 2, 7, 8 & 9. ATC zonal prices are affected, as are Midwest ISO average rates. Zonal ancillary services are not affected. ATC LLC changes rates effective Jan 1 in accordance with FERC approved rate phase-in plan. This also changes Midwest ISO average rates for Through/Out service, but do not impact the current discounted through-and-out rates for service requested after 7/01/02.

November 1, 2002:

Commission ordered change in allowed rate of return on equity reduced the revenue requirement for affected pricing zones. These changes will also affect the Midwest ISO formula rates for through-and-out transmission service, but do not impact the current discounted through-and-out rates for service requested after 7/01/02.



October 1, 2002:

Alliant Energy has increased their formula rates for transmission service only. These changes will also affect the Midwest ISO formula rates for through-and-out transmission service, but do not impact the current discounted through-and-out rates for service requested after 7/01/02.



July 1, 2002:

The Midwest ISO has discounted the firm rates for through and out service to the rates indicated in the above spreadsheet. The Midwest ISO commits to post rates no higher than these rates for a period of 18 months.



June 17, 2002:

Drive-Out rates for non-MISO member MAPP entities have been discounted.



June 1, 2002:

Rates for transmission requests made after midnight on June 1, 2002 (effective for June 1, 2002) will include changes representing the annual rate calculation. Also note that the Manitoba Hydro prices for all ancillary and transmission services change because a different currency exchange rate is applicable. These rates will be in effect until further notice. All other zonal transmission rates will remain unchanged at this time. Ancillary Service rates will also remain unchanged. We will post another message when these rates or other rates are further changed. The transmission service pricing spreadsheet has been updated.



May 1, 2002:

Rates for transmission requests made after midnight on May 1, 2002 (effective for May 1, 2002) will include changes made to the MISO Through and Out rate due to the inclusion of the Michigan Electric Transmission Company. These rates will be in effect until further notice. All other zonal transmission rates will remain unchanged at this time. Ancillary Service rates will also remain unchanged. We will post another message when these rates or other rates are further changed. The transmission service pricing spreadsheet has been updated.



April 09, 2002:

Rates for transmission requests made after midnight on April 10, 2002 (effective for April 11, 2002) for daily firm on-peak out and/or through point-to-point transmission service under the Midwest ISO OATT will be discounted to $80/MW-day. This rate includes both Schedule 7 and Schedule 14. The daily firm off-peak rate remains unchanged at this time. This rate will be in effect until further notice. All other zonal transmission rates will remain unchanged at this time. Ancillary Service rates will also remain unchanged. We will post another message when these rates or other rates are further changed. The transmission service pricing spreadsheet has been updated.



March 12, 2002:

Rates for transmission requests made after midnight on March 13, 2002 (effective for March 14, 2002) for the following out and/or through point-to-point transmission service rates under the Midwest ISO OATT will be discounted to the following rates:

 Schedule 8Schedule 14Total
Hourly non-firm on-peak     $0.75 / MWh      $2.25 / MWh      $3.00 / MWh     
Hourly non-firm off-peak      $0.43 / MWh      $1.07 / MWh      $1.50 / MWh     
Daily non-firm on-peak      $12 / MW-day      $36 / MW-day      $48 / MW-day     
Daily non-firm off-peak      $10 / MW-day      $26 / MW-day      $36 / MW-day     

These rates will be in effect until further notice. All other zonal transmission rates will remain unchanged at this time. Ancillary Service rates will also remain unchanged. We will post another message when these rates or other rates are further changed. The transmission service pricing spreadsheet has been updated.

February 15, 2002:

Rates for transmission requests made after midnight on February 16, 2002 for the following out and/or through point-to-point transmission service rates under the Midwest ISO OATT will be discounted to the following rates:
	Hourly non-firm off-peak:	$2/MWh
	Hourly non-firm on-peak:		$4/MWh
	Daily non-firm off-peak:		$48/MW-Day
	Daily non-firm on-peak:		$64/MW-Day
These rates will be in effect until further notice. All other zonal transmission rates will remain unchanged at this time. Ancillary Service rates will also remain unchanged. We will post another message when these rates or other rates are further changed. The transmission service pricing spreadsheet is now updated.

February 8, 2002:

MISO posted transmission prices that included the effect of rate changes for American Transmission Company. These rates became effective on January 1, 2002. The affected prices are the ATC zones, and for the system average (which is used for drive out and drive through rates).

January 31, 2002:

The Federal Energy Regulatory Commission approved a higher rate of return, from 10.5% to 13%, on the common equity (ROE) component of the formula used to calculate the rates for transmission service under Schedules 7, 8, and 9 of the Midwest ISO OATT. The rates as posted on the OASIS reflect the 13% ROE which became effective February 1, 2002, subject to refund pending an expedited hearing process.