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
October 1, 2026:
No Transmission Rates were changed in October 2026
Effective October 1, 2026
September 1, 2026:
No Transmission Rates were changed in September 2026
Effective September 1, 2026
Augest 1, 2026:
Rate changes were processed for the following items:
Schedules 26, 37 & 38:
- FERC Order EL22-34 implements resettlement of the 50-basis-point ROE adder for ATSI (FirstEnergy) and Duke Energy Ohio.
Ohio’s RTO participation mandate means the ROE adder is not an incentive and should not have been billed. The August update revises revenue requirements to establish the end of the refund period (back to February 24, 2022),
with limited Attachment GG scope. These changes primarily affect Schedule 26 distributions, with minor adjustments in Schedules 37 and 38 tied to legacy project allocations.
These changes are effective August 1, 2026.
July 1, 2026:
There were no Transmission Rate changes in July of 2026.
These changes are effective July 1, 2025.
June 1, 2026:
Rate changes were processed for the following item:
Schedule 1:
- Updated Schedule 1 expense amounts for Historical Transmission Owners. Updated divisors from the Attachment Os.
- The MISO average rate increased .355%.
- Schedule 7,8, & 9:
- Annual Rate Update of Annual Transmission Revenue Requirement (ATRR) for Historical Transmission Owners, Updated divisors from the Attachment Os.
- The MISO average rate decreased by -1.2%..
Schedule 26, 37, & 38:
- Annual Rate Update of Attachment GG Annual Transmission Revenue Requirement (ATRR) for Historical Transmission Owners, Updated divisors from the Attachment Os.
- The MISO average rate decreased by -2.312%.
Schedule 26-A:
- Annual Rate Update of Attachment MM Annual Transmission Revenue Requirement (ATRR) for Historical Transmission Owners, Updated divisors from the Attachment Os.
- The overall Revenue Requirement decreased by -0.04%.
Schedule 26C:
- Annual Rate Update of Attachment MM Annual Transmission Revenue Requirement (ATRR) for Historical Transmission Owners, Updated divisors from the Attachment Os.
- The overall Revenue Requirement decreased by -11.77%.
Schedule 26D:
- Rate Update of Annual Transmission Revenue Requirement (ATRR) for select number of forward-looking Transmission Owners to incorporate their 2024 True-Up adjustment at the correct ROE.
- TOs include: FE
- The overall Revenue Requirement increased by 0.001%.
Schedule 26E:
- Rate Update of Annual Transmission Revenue Requirement (ATRR) for select number of forward-looking Transmission Owners to incorporate their 2024 True-Up adjustment at the correct ROE.
- TOs include: NIPS
- The overall Revenue Requirement did not change.
Schedule 33:
- Ludington units 2, 3, & 5 were removed from rates, per Docket Number ER25-2771.
- Updated the Blackstart Service Revenue Requirement for participating Blackstart units. Updated the divisors for the Historical Transmission Owners as part of the June Rate Update. .
- The overall Revenue Requirement decreased by -0.093%.
Schedule 41:
- Annual update of Annual Transmission Revenue Requirement (ATRR) for Historical Transmission Owners. Updated the divisors for the Historical Transmission Owners as part of the June Rate Update.
- The overall Revenue Requirement decreased by -3.77%.
Schedule 42B:
- Annual update of Annual Transmission Revenue Requirement (ATRR) for historical Transmission Owners. Updated the divisors for the Historical Transmission Owners as part of the June Rate Update.
- The overall Revenue Requirement decreased by -3.92%.
Schedule 46:
- Updated the divisors for the Historical Transmission Owners as part of the June Rate Update.
- The MISO system average rate decreased by -2.09%.
These changes are effective June 1, 2025.
MAY 1, 2026:
Rate changes were processed for the following item:
- Schedule 7,8, & 9:
- Rate Update of Annual Transmission Revenue Requirement (ATRR) for select number of forward-looking Transmission Owners to incorporate their 2024 True-Up adjustment at the correct ROE.
- TOs include: ATC, ITC, ITCM, MMU, METC, NIPS, GRE
- The MISO average rate decreased by -0.003%.
- Schedule 26, 37, & 38:
- Rate Update of Annual Transmission Revenue Requirement (ATRR) for select number of forward-looking Transmission Owners to incorporate their 2024 True-Up adjustment at the correct ROE.
- TOs include: ATC, ITC, ITCM, METC, NIPS, GRE
- The MISO average rate increased by 0.01%.
- Schedule 26-A:
- Rate Update of Annual Transmission Revenue Requirement (ATRR) for select number of forward-looking Transmission Owners to incorporate their 2024 True-Up adjustment at the correct ROE.
- TOs include: ATC, ITC, ITCM, METC, NIPS, GRE
- The overall Revenue Requirement decreased by -0.07%
- Schedule 26C:
- Rate Update of Annual Transmission Revenue Requirement (ATRR) for select number of forward-looking Transmission Owners to incorporate their 2024 True-Up adjustment at the correct ROE.
- TOs include: NIPS
- The overall Revenue Requirement decreased by -0.28%
- Schedule 26E:
- Rate Update of Annual Transmission Revenue Requirement (ATRR) for select number of forward-looking Transmission Owners to incorporate their 2024 True-Up adjustment at the correct ROE.
- TTOs include: NIPS
- The overall Revenue Requirement decreased by -0.21%
These changes are effective May 1, 2025.
April 1, 2026:
Rate changes were processed for the following items:
- Schedules 7, 8 and 9:
- Sam Houston Electric Cooperative (“SHECO”) filed an updated Attachment O to replace the version previously used under its former agency arrangement with ETEC (East Texas Electric Cooperative). The new filing updates the template to reflect SHECO’s transition to stand-alone Transmission Owner status in MISO and revises the associated formula rate template and protocols. These revisions shift SHECO’s Annual Transmission Revenue Requirement (ATRR) from a historical calculation approach to a forward-looking methodology. These changes result in corresponding updates to SHECO’s Schedule 7, 8, and 9 Revenue Requirements.
- The annual rate increased by 0.04%.
These changes are effective April 1, 2026.
March 1, 2026:
There were no Transmission Rate changes in March of 2026.
These changes are effective March 1, 2025.
February 1, 2026:
Rate changes were processed for the following item:
- Schedule 1:
- Duke Energy Indiana (“DEI”) and Wabash Valley Power Association (“WVPA”) transitioned from a transmission revenue requirement calculated on a historical basis to a forward-looking basis resulting in updates to Schedule 1 Recoverable Expenses. The transition was processed in February 2026, with a related billing adjustment for January 2026. An update to load in the DEI and WVPA respective pricing zones also changes the overall MISO load, which resulted in a change to the MISO rate for Schedule 1.
- The MISO average rate increased by 1.24%
- Schedule 1:
- Updated Schedule 1 expense amounts, including 2024 True-Ups. Updated divisors from the Attachment Os.
- The MISO average rate decreased by 14.72%
- Schedules 7, 8 & 9:
- DEI and WVPA transitioned from a transmission revenue requirement calculated on a historical basis to a forward-looking basis resulting in updates to Schedule 7, 8, and 9 Revenue Requirements. The transition was processed in February 2026, with a related billing adjustment for January 2026. An update to load in the DEI and WVPA respective pricing zones also changes the overall MISO load, which resulted in a change to the MISO rate for Schedules 7, 8, and 9.
- The MISO average rate increased by 0.48%
- Schedules 26:
- DEI and WVPA transitioned from a transmission revenue requirement calculated on a historical basis to a forward-looking basis resulting in updates to Schedule 26 Revenue Requirements. The transition was processed in February 2026, with a related billing adjustment for January 2026. An update to load in the DEI and WVPA respective pricing zones also changes the overall MISO load, which resulted in a change to the MISO rate for Schedule 26.
- The MISO average rate increased by 0.01%
- Schedule 26-A:
- DEI and WVPA transitioned from a transmission revenue requirement calculated on a historical basis to a forward-looking basis resulting in updates to Schedule 26-A Revenue Requirements. The transition was processed in February 2026, with a related billing adjustment for January 2026. An update to load in the DEI and WVPA respective pricing zones also changes the overall MISO load, which resulted in a change to the MISO rate for Schedule 26-A.
- The overall revenue requirement increased by 0.04%
- Schedule 33:
- DEI and WVPA transitioned from a transmission revenue requirement calculated on a historical basis to a forward-looking basis resulting in updates to load. The transition was processed in February 2026, with a related billing adjustment for January 2026. An update to load in the DEI and WVPA respective pricing zones also changes the overall MISO load, which resulted in a change to the MISO rate for Schedule 33.
- The overall revenue requirement decreased by 0.01%
- Schedule 45:
- DEI and WVPA transitioned from a transmission revenue requirement calculated on a historical basis to a forward-looking basis resulting in updates to load. The transition was processed in February 2026, with a related billing adjustment for January 2026. An update to load in the DEI and WVPA respective pricing zones also changes the overall MISO load, which resulted in a change to the MISO rate for Schedule 45.
- The overall revenue requirement decreased by 0.02%
These changes are effective February 1, 2025.
January 1, 2026:
Rate changes were processed for the following item:
- Schedule 1:
- Updated Schedule 1 expense amounts, including 2024 True-Ups. Updated divisors from the Attachment Os.
- The MISO average rate decreased by 14.72%
- Schedules 7, 8 and 9:
- Annual Rate Update for forward-looking TOs, including the 2024 True-ups, updated divisors from the Attachment Os
- The MISO average rate increased by 7.14%
- Schedules 26, 37 and 38:
- Updated Attachment GG revenue requirements for forward-looking TOs, including 2024 True-Ups. Updated divisors from the Attachment Os. This is also year 13 of a 13-year phase-in of the Entergy-only RTOR average rate being charged on transactions exiting the MISO South system.
- The MISO average rate increased by 5.71%
- Schedules 26-A & 39:
- Annual update for forward-looking Transmission Owners, including 2024 True ups.
- The overall revenue requirement increased by 13.35%
- Schedules 26-C:
- Cost recovery for TMEPs (Targeted Market Efficiency Projects) to reflect updates from MISO, including 2024 True-ups.
- The overall revenue requirement increased by 3.46%
- Schedules 26-D:
- Cost recovery for TMEPs (Targeted Market Efficiency Projects) to reflect updates provided from PJM. MISO is required to incorporate their ATRR in the Sch. 26D Rate calc.
- The overall revenue requirement decreased by 11.18%
- Schedule 26-E:
- Cost recovery for IMEPs (Interregional Market Efficiency Projects) to reflects updates for NIPSCO, including 2024 True-ups.
- The overall revenue requirement increased by 4.55%
- Schedule 33:
- Updated the divisors for the forward-looking Transmission Owners as part of the January Rate Update.
- The MISO average rate decreased by 0.26%
- Schedule 45:
- Annual update for forward-looking transmission owners, including 2024 True-ups. Updated divisors from the Attachment O’s.
- The MISO average rate decreased by 4.79%
These changes are effective January 1, 2025.
December 1, 2025:
Rate changes were processed for the following item:
- Schedule 1:
- Manitoba Hydro’s (MHEB) transmission rates were updated with a December 1, 2025, effective date.
- The MHEB annual rate increased by 17.56%
- Schedule 7:
- Manitoba Hydro’s (MHEB) transmission rates were updated with a December 1, 2025, effective date.
- The MHEB annual rate increased by 1.744%.
- Schedule 8:
- Manitoba Hydro’s (MHEB) transmission rates were updated with a December 1, 2025, effective date.
- The MHEB monthly rate (Schedule 8 does not have an annual product) decreased by .298%.
Effective December 1, 2025
November 1, 2025:
No Transmission Rates were changed in November
Effective November 1, 2025
October 1, 2025:
No Transmission Rates were changed in October
Effective October 1, 2025
September 1, 2025:
No Transmission Rates were changed in September
Effective September 1, 2025
August 1, 2025:
Rate changes were processed for the following items:
- Schedules 33
- Added the revenue requirements of the MCV Unit 9.
- The MISO system average rate increased by 45.54%.
These changes are effective August 1, 2025.
July 1, 2025:
No Transmission Rates were changed in July
Effective July 1, 2025
June 1, 2025:
Rate changes were processed for the following items:
- Schedule 1:
- Updated Schedule 1 expense amounts for Historical Transmission Owners. Updated divisors from the Attachment Os.
- The MISO average rate increased .904%
- Schedules 7, 8 and 9:
- Annual Rate Update of Annual Transmission Revenue Requirement (ATRR) for Historical Transmission Owners, Updated divisors from the Attachment Os.
- The MISO Schedule 7, 8 and 9 rate decreased by 0.01%.
- Schedules 26, 37 and 38:
- Annual Rate Update of Attachment GG Annual Transmission Revenue Requirement (ATRR) for Historical Transmission Owners, Updated divisors from the Attachment Os.
- The MISO average rate decreased by 1.21%
- Schedules 26-A:
- Annual Rate Update of Attachment MM Annual Transmission Revenue Requirement (ATRR) for Historical Transmission Owners, Updated divisors from the Attachment Os.
- The overall Revenue Requirement increased by 0.04%
- Schedules 26-D:
- Cost recovery for TMEPs (Targeted Market Efficiency Projects) to reflect updates provided from PJM. MISO is required to incorporate their ATRR in the Sch. 26D Rate calc.
- The overall Revenue Requirement Increased by 77.10%.
- Schedule 26-E:
- Cost recovery for IMEPs (Interregional Market Efficiency Projects) to reflects updates for NIPSCO, including 2023 True-ups.
- The overall Revenue Requirement Increased by 2.22%.
- Schedule 33:
- Updated the Blackstart Service Revenue Requirement for participating Blackstart units. Updated the divisors for the Historical Transmission Owners as part of the June Rate Update.
- The MISO system average rate decreased by 0.84%
- Schedule 41:
- Annual update of Annual Transmission Revenue Requirement (ATRR) for Historical Transmission Owners. Updated the divisors for the Historical Transmission Owners as part of the June Rate Update.
- The overall Revenue Requirement increased by 31.63%
- Schedule 42B:
- Annual update of Annual Transmission Revenue Requirement (ATRR) for historical Transmission Owners. Updated the divisors for the Historical Transmission Owners as part of the June Rate Update.
- The overall Revenue Requirement decreased by 4.58%
- Schedule 45:
- Updated the divisors for the Historical Transmission Owners as part of the June Rate Update.
- The MISO system average rate decreased by 1.07%
These changes are effective June 1, 2025.
May 1, 2025:
No Transmission Rates were changed in May
Effective May 1, 2025
April 1, 2025:
No Transmission Rates were changed in April
Effective April 1, 2025
March 1, 2025:
No Transmission Rates were changed in March
Effective March 1, 2025
February 1, 2025:
Rate changes were processed for the following items:
- Schedules 7, 8 and 9:
- Missouri Joint Municipal Electric Utility Commission (MEC1) transmission rates were updated with a January 1, 2025 effective date.
- Citizens Energy (CECT), a new Transmission Owner, was added to Transmission Pricing Zone 3B with a February 1, 2025 Effective date.
- The annual rate increased by 0.23%.
- Schedules 26A
- Great River Energy (GRE) transmission revenue requirement was updated due to an unintentional error identified by Tariff Pricing while extracting the revenue requirements for the 26A project, 23370 Iron Range - Benton County, for the January rate development.
- The overall Revenue Requirement increased by 0.08%.
These changes are effective February 1, 2025.
January 1, 2025:
Rate changes were processed for the following items:
- Schedule 1:
- Updated Schedule 1 expense amounts, including 2023 True-Ups. Updated divisors from the Attachment Os
- The MISO average rate increased by 10.01%
- Schedules 7, 8 and 9:
- Annual Rate Update for forward-looking TOs, including the 2023 True-ups, updated divisors from the Attachment Os
- The MISO Schedule 7, 8 and 9 rate increased by 3.73%.
- Schedules 26, 37 and 38:
- Updated Attachment GG revenue requirements for forward-looking TOs, including 2023 True-Ups. Updated divisors from the Attachment Os. This is also year 12 of a 13-year phase-in of the Entergy-only RTOR average rate being charged on transactions exiting the MISO South system.
- The MISO average rate increased by 0.37%.
- Schedules 26-A, and 39
- Annual update for forward-looking Transmission Owners, including 2023 True ups.
- The overall Revenue Requirement increased by 5.62%.
- Schedules 26-C:
- Cost recovery for TMEPs (Targeted Market Efficiency Projects) to reflect updates from MISO, including 2023 True-ups.
- The overall Revenue Requirement increased by 1.41%
- Schedules 26-D:
- Cost recovery for TMEPs (Targeted Market Efficiency Projects) to reflect updates provided from PJM. MISO is required to incorporate their ATRR in the Sch. 26D Rate calc.
- The overall Revenue Requirement Increased by 77.10%.
- Schedule 26-E:
- Cost recovery for IMEPs (Interregional Market Efficiency Projects) to reflects updates for NIPSCO, including 2023 True-ups.
- The overall Revenue Requirement Increased by 2.22%.
- Schedule 33:
- Updated the divisors for the forward-looking Transmission Owners as part of the January Rate Update.
- The MISO system average rate decreased by 0.35%.
- Schedule 42-B:
- Annual update for forward-looking transmission owners, including 2023 True-ups. Updated divisors from the Attachment O’s.
- MISO rate decreased by 0.13%
- Schedule 45:
- Annual update for forward-looking transmission owners, including 2023 True-ups. Updated divisors from the Attachment O’s.
- MISO rate increased by 12.88%
These changes are effective January 1, 2025.
December 1, 2024:
Rate changes were processed for the following items:
No Transmission Rates were changed in December of 2024.
These changes are effective December 1, 2024.
November 1, 2024:
Rate changes were processed for the following items:
No Transmission Rates were changed in November of 2024.
These changes are effective November 1, 2024.
October 1, 2024:
Rate changes were processed for the following items:
No Transmission Rates were changed in October of 2024
These changes are effective October 1, 2024.
September 1, 2024:
Rate changes were processed for the following items:
- Schedule 1:
- Manitoba Hydro’s (MHEB) transmission rates were updated with a September 1, 2024 effective date. (Exhibit 1)
- The MHEB annual rate decreased by 1.70%.
- Schedules 7:
- Manitoba Hydro’s (MHEB) transmission rates were updated with a September 1, 2024 effective date. (Exhibit 1)
- The MHEB annual rate decreased by 1.70%.
- Schedule 8:
- Manitoba Hydro’s (MHEB) transmission rates were updated with a September 1, 2024 effective date. (Exhibit 1)
- The MHEB monthly rate(Schedule 8 does not have an annual product) decreased by 1.70%.
These changes are effective September 1, 2024.
August 1, 2024:
Rate changes were processed for the following items:
No Transmission Rates were changed in August of 2024
These changes are effective August 1, 2024.
July 1, 2024:
Rate changes were processed for the following items:
- Schedule 7,8 and 9:
- Rate changes were processed to incorporate an inadvertent error made in Michigan Join Zone, 13A and the Michigan Joint Zone SubZone 13. 95MW associated with MPPA AREF NL1135 was omitted in error in the Michigan Joint Zone & Michigan Joint Subzone Transmission Rate calcs for June 2024.
- The Michigan Joint Zone average rate decreased by .218%.
- The Michigan Joint Zone Subzone rate decreased by 1.345%.
- Schedule 26:
- Rate changes were processed to incorporate an inadvertent error made in Michigan Join Zone, 13A and the Michigan Joint Zone SubZone 13. 95MW associated with MPPA AREF NL1135 was omitted in error in the Michigan Joint Zone & Michigan Joint Subzone Transmission Rate calcs for June 2024.
- The Michigan Joint Zone average rate decreased by .005%.
- The Michigan Joint Zone Subzone rate decreased by 1.345%.
- Schedule 41:
- Rate changes were processed for Entergy to recover for Hurricanes Laura, Delta, Zeta, and Ida, as well as Winter Storm Uri from transmission customers.
- The Entergy New Orleans rate increased by 153.615%.
- The Entergy Louisiana rate increased by 100%.
- The Entergy Texas rate increased by 100%.
These changes are effective July 1, 2024.
June 1, 2024:
Rate changes were processed for the following items:
- Schedule 1:
- Updated Schedule 1 expense amounts for Historical Transmission Owners. Updated divisors from the Attachment Os.
- The MISO average rate increased .326%
- Schedule 7,8 & 9:
- Annual Rate Update of Annual Transmission Revenue Requirement (ATRR) for Historical Transmission Owners, Updated divisors from the Attachment Os.
- Although it did not affect their ATRR calculation, MEAN went from a 30.9 Customer to a full Historical TO.
- The MISO Schedule 7, 8 and 9 rate increased by 10.472%
- Schedule 26,37 & 38:
- Annual Rate Update of Attachment GG Annual Transmission Revenue Requirement (ATRR) for Historical Transmission Owners, Updated divisors from the Attachment Os.
- The MISO average rate increased by 1.647%
- Schedule 26-A & 39:
- Annual Rate Update of Attachment MM Annual Transmission Revenue Requirement (ATRR) for Historical Transmission Owners, Updated divisors from the Attachment Os.
- The overall Revenue Requirement decreased by 2.548%
- Schedule 26-C:
- Updated Revenue requirement (ATRR) for IPL’s (TMEPS) Project 16228.
- The overall Revenue Requirement increased by 60.329% driven by an increase in IPL’s project net plant.
- Schedule 33:
- Updated the Blackstart Service Revenue Requirement for participating Blackstart units. Updated the divisors for the Historical Transmission Owners as part of the June Rate Update.
- The MISO system average rate increased by 1.4%
- Schedule 41:
- Annual update of Annual Transmission Revenue Requirement (ATRR) for Historical Transmission Owners. Updated the divisors for the Historical Transmission Owners as part of the June Rate Update. ETTO reached the end of their recovery period for Hurricanes Gustav and Ike.
- The overall Revenue Requirement decreased by 95.282% because ETTO reached the end of their recovery period for Hurricanes Gustav and Ike.
- Schedule 42B:
- Annual update of Annual Transmission Revenue Requirement (ATRR) for historical Transmission Owners. Updated the divisors for the Historical Transmission Owners as part of the June Rate Update.
- The overall Revenue Requirement decreased by 2.478%
- Schedule 45:
- Updated the divisors for the Historical Transmission Owners as part of the June Rate Update.
- The MISO system average rate increased by 1.399%
These changes are effective June 1, 2024.
May 1, 2024:
Rate changes were processed for the following items:
- Schedule 33:
- Added the revenue requirements of the WPSC Gaylord Blackstart Units 1-3.
- The MISO system average rate increased by 5.563%.
These changes are effective May 1, 2024.
April 1, 2024:
No Transmission Rates were changed in April
Effective April 1, 2024
March 1, 2024:
No Transmission Rates were changed in March
Effective March 1, 2024
February 1, 2024:
Rate changes were processed for the following items:
- Schedule 1
- American Transmission Company (ATC) provided a late change to their 2024 Projected Subzone Loads (allowed in “Schedule 9 – ATC” tariff language). Since this change was submitted after the MISO Tariff Pricing imposed deadline, this change was processed in February, 2024, with a related billing adjustment for January, 2024. A change to loads in the ATC Subzones also changes the total MISO load, which has an effect on the overall MISO rate for Schedules 1, 7/8/9, 26, 33, & 45.
- The Overall MISO Rate increased .014%
- Schedule 7,8,&9
- American Transmission Company (ATC) provided a late change to their 2024 Projected Subzone Loads (allowed in “Schedule 9 – ATC” tariff language). Since this change was submitted after the MISO Tariff Pricing imposed deadline, this change was processed in February, 2024, with a related billing adjustment for January, 2024. A change to load in the ATC Subzones also changes the total MISO load, which has an effect on the overall MISO rate for Schedules 1, 7/8/9, 26, 33, & 45.
- The ATC Subzone load changes also re-shuffled the ATC Subzone revenue requirements for Schedule 7, 8, and 9. .
- The Overall MISO rate increased .014%.
- Schedule 26
- American Transmission Company (ATC) provided a late change to their 2024 Projected Subzone Loads (allowed in “Schedule 9 – ATC” tariff language). Since this change was submitted after the MISO Tariff Pricing imposed deadline, this change was processed in February, 2024, with a related billing adjustment for January, 2024. A change to loads in the ATC Subzones also changes the total MISO load, which has an effect on the overall MISO rate for Schedules 1, 7/8/9, 26, 33, & 45.
- The Overall MISO Rate increased .014%
- Schedule 33
- American Transmission Company (ATC) provided a late change to their 2024 Projected Subzone Loads (allowed in “Schedule 9 – ATC” tariff language). Since this change was submitted after the MISO Tariff Pricing imposed deadline, this change was processed in February, 2024, with a related billing adjustment for January, 2024. A change to loads in the ATC Subzones also changes the total MISO load, which has an effect on the overall MISO rate for Schedules 1, 7/8/9, 26, 33, & 45.
- The Overall MISO Rate increased .014%
- Schedule 45
- American Transmission Company (ATC) provided a late change to their 2024 Projected Subzone Loads (allowed in “Schedule 9 – ATC” tariff language). Since this change was submitted after the MISO Tariff Pricing imposed deadline, this change was processed in February, 2024, with a related billing adjustment for January, 2024. A change to loads in the ATC Subzones also changes the total MISO load, which has an effect on the overall MISO rate for Schedules 1, 7/8/9, 26, 33, & 45.
- The Overall MISO Rate increased .014%
These changes are effective February 1, 2024.
January 1, 2024:
Rate changes were processed for the following items:
- Schedule 1
- Updated Schedule 1 expense amounts, including 2022 True-Ups. Updated divisors from the Attachment Os.
- The MISO average rate increased .99%
- Schedule 7,8,&9
- Annual Rate Update for forward-looking TOs, including the 2022 True-ups, updated divisors from the Attachment Os.
- The MISO Schedule 7, 8 and 9 rate increased by 6.513%.
- Schedule 26, 27, 28
- Updated Attachment GG revenue requirements for forward-looking TOs, including 2022 True-Ups. Updated divisors from the Attachment Os. This is also year 11 of a 13-year phase-in of the Entergy-only RTOR average rate being charged on transactions exiting the MISO South system.
- The MISO average rate decreased by 2.029%.
- Schedule 26-A & 39
- Annual update for forward-looking Transmission Owners, including 2022 True-ups.
- The overall Revenue Requirement increased by 8.12 %.
- Schedule 26-C
- Cost recovery for TMEPs (Targeted Market Efficiency Projects) to reflect updates from MISO, including 2022 True-ups.
- The overall Revenue Requirement increased by 1.22%.
- Schedule 26-D
- Cost recovery for TMEPs (Targeted Market Efficiency Projects) to reflect updates from PJM. The driver for this large decrease is normal depreciation on the sole First Energy (PJM) project that is being recovered under this Schedule. The year over year decrease is consistent with prior years for this project.
- The overall Revenue Requirement decreased by 37.34%.
- Schedule 26-E
- Cost recovery for IMEPs (Interregional Market Efficiency Projects) to reflects updates for NIPSCO, including 2022 True-ups.
- The overall Revenue Requirement decreased by 4.82%.
- Schedule 33
- Updated the divisors for the forward-looking Transmission Owners as part of the January Rate Update.
- The MISO system average rate decreased by .052%.
- Schedule 45
- Annual update for forward-looking transmission owners, including 2022 True-ups. Updated divisors from the Attachment O’s.
- MISO rate decreased by 12.25%
These changes are effective January 1, 2024.
December 1, 2023:
No Transmission Rates were changed in December
Effective December 1, 2023
November 1, 2023:
No Transmission Rates were changed in November
Effective November 1, 2023
October 1, 2023:
No Transmission Rates were changed in October
Effective October 1, 2023
September 1, 2023:
Rate changes were processed for the following items:
- Schedule 1
- Wabash Valley (WVPA) was authorized to add transmission facilities and related load in the AES (IPL) zone per the order in Docket ER23-2261. The new load in the AES (IPL) zone also changes the total MISO load, which has an effect on the overall MISO rate for Schedules 1, 7/8/9, 26, 33, & 45.
- Manitoba Hydro’s (MHEB) annual rates were updated with a September 1, 2023 effective date.
- The Overall MISO Rate decreased .022%
- Schedule 2
- Manitoba Hydro’s (MHEB) rate was updated to zero.
- The Overall Schedule 2 rate decreased 100%.
- Schedule 7, 8 & 9
- Wabash Valley (WVPA) was authorized to add transmission facilities and related load in the AES (IPL) zone per the order in Docket ER23-2261. The new load in the AES (IPL) zone also changes the total MISO load, which has an effect on the overall MISO rate for Schedules 1, 7/8/9, 26, 33, & 45.
- Manitoba Hydro’s (MHEB) annual rates were updated with a September 1, 2023 effective date.
- The Overall MISO rate decreased .013%.
- Schedule 26
- Wabash Valley (WVPA)was authorized to add transmission facilities and related load in the AES (IPL) zone per the order in Docket ER23-2261. The new load in the AES (IPL) zone also changes the total MISO load, which has an effect on the overall MISO rate for Schedules 1, 7/8/9, 26, 33, & 45.
- The overall MISO rate decreased .022%
- Schedule 33
- Wabash Valley (WVPA) was authorized to add transmission facilities and related load in the AES (IPL) zone per the order in Docket ER23-2261. The new load in the AES (IPL) zone also changes the total MISO load, which has an effect on the overall MISO rate for Schedules 1, 7/8/9, 26, 33, & 45.
- The overall MISO rate decreased .021%.
- Schedule 45
- Wabash Valley (WVPA) was authorized to add transmission facilities and related load in the AES (IPL) zone per the order in Docket ER23-2261. The new load in the AES (IPL) zone also changes the total MISO load, which has an effect on the overall MISO rate for Schedules 1, 7/8/9, 26, 33, & 45.
- The overall MISO rate decreased .022%.
These changes are effective September 1, 2023.
August 1, 2023:
No Transmission Rates were changed in August
Effective August 1, 2023
July 1, 2023:
No Transmission Rates were changed in July
Effective July 1, 2023
June 1, 2023:
Rate changes were processed for the following items:
- Schedule 1
- Updated Schedule 1 expense amounts for Historical Transmission Owners. Updated divisors from the Attachment Os.
- The MISO average rate decreased by 3.32%.
- Schedule 7, 8 & 9
- Annual Rate Update of Annual Transmission Revenue Requirement (ATRR) for Historical Transmission Owners, Updated divisors from the Attachment Os.
- Added Jonesboro as a new TO.
- MISO Average rate decreased by 5.00%.
- Schedule 26,37 & 38
- Annual Rate Update of Annual Transmission Revenue Requirement (ATRR) for Historical Transmission Owners, Updated divisors from the Attachment Os.
- MISO Average rate decreased by 1.215%.
- Schedule 26-A & 39
- Annual update of Annual Transmission Revenue Requirement (ATRR) for historical Transmission Owners.
- The overall Revenue Requirement increase by .02%.
- Schedule 26-C
- Updated for new Indianapolis Power and Light (TMEPS) Project
- The Overall MISO rate increased by 57.28%
- Schedule 26-D
- Updated Revenue requirement (ATRR) for First Energy for their (TMEPS) Project
- The Overall MISO rate increased by .01%
- Schedule 33
- Updated the revenue credit info for participating Blackstart units. Updated the divisors for the Historical Transmission Owners as part of the June Rate Update.
- The MISO system average rate decreased by 1.18%.
- Schedule 41
- Annual update of Annual Transmission Revenue Requirement (ATRR) for historical Transmission Owners. Updated the divisors for the Historical Transmission Owners as part of the June Rate Update. Hurricane Katrina & Rita recovery ended for ETTO.
- The overall Revenue Requirement decreased by 63.69%.
- Schedule 42B
- Annual update of Annual Transmission Revenue Requirement (ATRR) for historical Transmission Owners. Updated the divisors for the Historical Transmission Owners as part of the June Rate Update.
- The MISO system average rate decreased by 3.69%.
- Schedule 45
- Updated the divisors for the Historical Transmission Owners as part of the June Rate Update.
- The MISO system average rate decreased by 1.18%.
These changes are effective June 1, 2023.
May 1, 2023:
No Transmission Rates were changed in May
April 1, 2023:
Rate changes were processed for the following items:
- Schedule 26
- Correction of minor MTEP Project Zonal Allocation percentages for certain MTEP19, MTEP20, and MTEP21 projects.
- The MISO-wide Schedule 26 rate remained the same. Schedule 26 zonal rates have minorchanges to them since this was a zonal re-allocation.
These changes are effective April 1, 2023.
March 1, 2023:
No Transmission Rates were changed in March.
February 1, 2023:
Rate changes were processed for the following items:
- Schedule 2
- Per Docket ER23-523, Schedule 2 Reactive Power and voltage Control from generation or other source service was eliminated in all Zones.
- The MISO Schedule 2 rate decreased by 100%.
These changes are effective February 1, 2023.
January 1, 2023:
Rate changes were processed for the following items:
- Schedule 1
- Updated Schedule 1 expense amounts, including 2021 True-Ups. Updated divisors from the Attachment Os.
- The MISO average rate decreased by .74%.
- Schedule 2
- Per Docket ER22-526, Glacier Sands Wind Power's (GSWP) Revenue Requirement was updated in Zone 3A.
- Per Docket ER23-311, Weston's (WPS) Revenue Requirement was reduced due to the suspension of Weston unit 2 from Zone 2B. (Exhibit 2)
- Per Docket ER23-47, Endeavor Wind I (FPLP) was added to Zone 1. (Exhibit 3).
- Per Docket ER23-273, Badger Hollow I (WPS) was added to Zone 2C. (Exhibit 4)
- Per Docket ER23-163, Units Edwards 2 and 3 (AMEM) were removed from Zone 3A Due to their suspension. (Exhibit 5)
- Per Docket ER23-107 Meramec (AMMO) was removed from Zone 3B due to their retirement. (Exhibit 6)
- Per Docket ER21-281 MEC's (MEC) Stated rate was updated in Zone 24 due to the suspension of their unit Riverside. (Exhibit 7)
- The MISO Schedule 2 rate decreased by 2.27%.
- Schedule 7,8 & 9
- Annual Rate Update for forward-looking TOs, including the 2021 True-ups, updated divisors from the Attachment Os and Annual update of the Entergy-only RTOR (Regional Through & Out Rate - year 10 of a 10-year phase-in). Starting 1/1/2023 the MISO-Wide Average Rate and the Entergy RTOR Rate will be the same.)
- Addition of MJMEUC (new TO) in the Ameren, MO TPZ (Zone 3B). (Exhibit 8)
- The MISO Schedule 7, 8 and 9 rate increased by 3.19%.
- Schedule 26, 37 & 38
- Updated Attachment GG revenue requirements for forward-looking TOs, including 2021 True-Ups. Updated divisors from the Attachment Os. This is also year 10 of a 13-year phase-in of the Entergy-only RTOR average rate being charged on transactions exiting the MISO South system.
- The MISO average rate decreased by 1.89%.
- Schedule 26-A & 39
- Annual update for forward-looking Transmission Owners.
- The overall Revenue Requirement increased by 1.55%.
- Schedule 26-C
- Cost recovery for TMEPs (Targeted Market Efficiency Projects) to reflect updates from MISO
- The overall Revenue Requirement decreased by 11.03%.
- Schedule 26-D
- Cost recovery for TMEPs (Targeted Market Efficiency Projects) to reflect updates from PJM.
- The overall Revenue Requirement decreased by 34.14%.
- Schedule 26-E
- Cost recovery for IMEPs (Interregional Market Efficiency Projects) to reflects updates for NIPSCO.
- The overall Revenue Requirement increased by 1230.01%.
- Schedule 33
- Updated the divisors for the forward-looking Transmission Owners as part of the January Rate Update.
- The MISO system average rate decreased by .19%.
- Schedule 45
- Annual update for forward-looking transmission owners. Updated divisors from the Attachment Os.
- The MISO system average rate decreased by .19%.
These changes are effective January 1, 2023.
December 1, 2022:
Rate changes were processed for the following items:
- Schedule 2
- Per Docket ER22-2976, Point Beach Solar (WPPI) was added to Zone 2B.
- Per Docket ER22-2763, Lake Charles Power Station (ELMP) was added to Zone 29.
- Per Docket ER22-2832, Cardinal Point (CPW) was added to Zone 3A.
- Per Docket ER22-2942, Endeavor Wind II (FPLP) was added to Zone 1.
- Per Docket ER22-2329, Minonk Wind's (MINK) Revenue Requirement was updated in Zone 3A.
- Per Docket ER22-1554, Ford County Wind's (TNSK) Revenue Requirement was updated in Zone 3A
- The MISO Schedule 2 rate increased by 2.33%.
These changes are effective December 1, 2022.
November 1, 2022:
Rate changes were processed for the following items:
- Schedule 2
- Per Docket ER22-728, Pegasus Wind LLC (PEG1) Revenue Requirement was updated in Zone 10.
- Per Docket ER22-2777, Tilton Energy (Tilt) Revenue Requirement was updated in Zone 3A.
- Per Docket ER22-2774, Gibson City (SIGC) Revenue Requirement was updated in Zone 3A.
- Per Docket ER22-2776, Shelby Energy (SIGC) Revenue Requirement was updated in Zone 3A.
- Per Docket ER22-93, Tatanka Ridge Wind Farm (TRWL) Revenue Requirement was updated in Zone 18.
- Per Docket ER22-1815, Mulligan Solar (TNSK) was added to Zone 3A.
- Per Docket ER22-1980, Deuel Harvest (DHWE) was added to Zone 18.
- The MISO Schedule 2 rate increased by 1.74%.
These changes are effective November 1, 2022.
October 1, 2022:
Rate changes were processed for the following items:
- Schedule 2
- Per Docket ER21-2695, Lincoln Land Wind, LLC's (LLW) Revenue Requirement was updated in Zone 3A.
- The MISO Schedule 2 rate decreased by 1.20%.
These changes are effective October 1, 2022.
September 1, 2022:
Rate changes were processed for the following items:
- Schedule 2
- Per Docket EL22-71, City Water, Light and Power (CWLP) was removed from Zone 7.
- Per Docket ER21-762, Bishop Hill Energy II's (BHII) Revenue Requirement was updated in Zone 3A.
- Per Docket ER22-80 Coyote Ridge's (GOOG) Revenue Requirement was updated in Zone 16.
- The MISO Schedule 2 rate decreased by .71%.
These changes are effective September 1, 2022.
August 1, 2022:
Rate changes were processed for the following items:
- Schedule 2
- Per Docket ER22-1610, Big River Solar (GALT) was added to Zone 3A.
- The MISO Schedule 2 rate increased by 0.98%.
These changes are effective August 1, 2022.
July 1, 2022:
Rate changes were processed for the following items:
- Schedule 2
- Per Docket ER22-1554, Ford County Wind (TNSK) was added to Zone 3A.
- Per Docket ER22-93, Tatanka Ridge Wind Farm (TRWL) was added to Zone 18
- Per Docket ER22-616, Dressor Plains Solar (WVPA) was added to Zone 3A.
- Per Docket ER22-615, Prairie State Solar (WVPA) was added to Zone 3A.
- Per Docket ER21-2521, Broadlands Wind Farm LLC's (BRDL) Revenue Requirement was updated in Zone 3A.
- Per Docket ER21-2816, Gratiot's (GCW) Revenue Requirement was updated in Zone 13.
- The MISO Schedule 2 rate increased by 2.13%
- Schedule 26 & 38
- During the January 2022 Transmission Rate Update, an error was made while updating the Transmission Rate Tool (TRT). While reviewing TRT information for the June 2022 Transmission Rate Update, we noticed the problem with the ITC Midwest Sch. 26 & Sch. 26A information.
- With the advice from Legal, we decided to correct the error in July 2022, and make retroactive corrections back to January 2022.
- The ATRR impact of the corrections for Sch. 26 is an increase of $855,633.
- Overall, MISO Schedule 26 rate increased by .20%.
- Schedule 26-A
- During the January 2022 Transmission Rate Update, an error was made while updating the Transmission Rate Tool (TRT). While reviewing TRT information for the June 2022 Transmission Rate Update, we noticed the problem with the ITC Midwest Sch. 26 & Sch. 26A information.
- With the advice from Legal, we decided to correct the error in July 2022, and make retroactive corrections back to January 2022.
- The ATRR impact of the corrections for Sch. 26A is an increase of $5,210,597.
- The overall Revenue Requirement increased by .73%.
These changes are effective July 1, 2022.
June 1, 2022:
Rate changes were processed for the following items:
- Schedule 1
- Updated Schedule 1 expense amounts for Historical Transmission Owners. Updated divisors from the Attachment O’s.
- The MISO average rate decreased by 3.80%.
- Schedule 2
- Per Docket ER21-2968, Kuester 1-7 (UMRC) Revenue Requirement was updated in Zone 2D.
- Per Docket ER21-2968, Mihm 1-3 (UMRC) Revenue Requirement was updated in Zone 2E.
- Per Docket No. EL21-88 and ER21-2446, Great River Energy (GREM) Zone 8, sold Coal Creek Units 1 and 2 to Rainbow Energy (REC1) Zone 8.
- Per the cases submitted in Dynamics, Carville Unit (ETMP), Zone 29, was transferred to Entergy Louisiana (ELMP), Zone 29.
- Per the Attachment Y, Baxter Wilson - Unit 1 (EMMP) was removed from Zone 30 due to their suspension.
- Per the Attachment Y, Trenton Channel 9 (DEMO) was removed from Zone 10 due to their suspension.
- Per the Attachment Y, St. Clair 2, 3, 6 and 7 (DEMO) were removed from Zone 10 due to their suspension.
- The MISO Schedule 2 rate decreased by 2.29%.
- Schedule 7, 8 & 9
- Annual Rate Update of Annual Transmission Revenue Requirement (ATRR) for Historical Transmission Owners, Updated divisors from the Attachment O’s.
- MISO Average rate increased by 1.38%.
- Schedule 26,37 & 38
- Annual Rate Update of Annual Transmission Revenue Requirement (ATRR) for Historical Transmission Owners, Updated divisors from the Attachment O’s.
- MISO Average rate decreased by 1.96%.
- Schedule 26-A & 39
- Annual update of Annual Transmission Revenue Requirement (ATRR) for historical Transmission Owners.
- The overall Revenue Requirement decreased by .03%
- Schedule 33
- Annual update of Annual Transmission Revenue Requirement (ATRR) for historical Transmission Owners. Updated the divisors for the Historical Transmission Owners as part of the June Rate Update.
- The MISO system average rate decreased by 1.41%.
- Schedule 41
- Annual update of Annual Transmission Revenue Requirement (ATRR) for historical Transmission Owners. Updated the divisors for the Historical Transmission Owners as part of the June Rate Update.
- The overall Revenue Requirement decreased by 45.51%
- Schedule 42B
- Annual update of Annual Transmission Revenue Requirement (ATRR) for historical Transmission Owners. Updated the divisors for the Historical Transmission Owners as part of the June Rate Update.
- The MISO system average rate decreased by 3.78%.
- Schedule 45
- Updated the divisors for the Historical Transmission Owners as part of the June Rate Update.
- The MISO system average rate decreased by 1.41%.
These changes are effective June 1, 2022.
May 1, 2022:
Rate changes were processed for the following items:
- Schedule 2
- Per Docket ER21-1046, Sugar Creek Wind One’s (TNSK) Revenue Requirement was updated in Zone 3A.
- Per Docket ER22-1136, Sac County Wind LLC (FPLP) was added to Zone 24.
- Per Docket ER22-80, Coyote Ridge (GOOG) was added to Zone 16.
- The MISO Schedule 2 rate increased by .17%.
These changes are effective May 1, 2022.
April 1, 2022:
Rate changes were processed for the following items:
- Schedule 2
- Per Docket ER21-2329, Minonk Wind (MINK) was added to Zone 3A.
- Per Docket ER22-865, Glaciers Edge Wind (GOOG) was added to Zone 24.
- Per Docket ER21-1622, Ashtabula 1 Wind, Astoria Station, Big Stone Plant, Coyote Station, Jamestown Units 1 and 2, Lake Preston, Langdon Wind, Luverne Wind, and Solway's (OTP) Revenue Requirement was updated in Zone 18.
- Per Docket ER21-1622, Merricourt Wind Energy (MDU) Revenue Requirement was updated in Zone 15.
- Per Docket ER21-1339, California Ridge Wind (CALR) Revenue Requirement was updated in Zone 3A.
- Per Docket ER21-2179, Oliver Wind I (FPLP) Revenue Requirement was updated in Zone 14.
- Per Docket ER21-2401, Oliver Wind II (FPLP) Revenue Requirement was updated in Zone 14.
- The MISO Schedule 2 rate increased by .07%.
These changes are effective April 1, 2022.
March 1, 2022:
Rate changes were processed for the following items:
- Schedule 2
- Per Docket ER22-728, Pegasus Wind LLC (PEG1) was added to Zone 10.
- Per Docket ER21-2816, Gratiot (GCW) was added to Zone 13.
- Per Docket ER20-2550, Choctaw County Generating Station (EMMP) Revenue Requirement was updated in Zone 30.
- The MISO Schedule 2 rate decreased by .53%.
These changes are effective March 1, 2022.
February 1, 2022:
Rate changes were processed for the following items:
- Schedule 2
- Per Docket ER22-420, Two Creeks 1 (WPS) was added to Zone 2B..
- Per Docket ER22-526, Glacier Sands Wind Power (GSWP) was added to Zone 3A.
- Per Docket ER21-1215, Assembly Solar I (MPPA) was added to Zone 13.
- Per Docket ER21-2449, Assembly Solar II (MPPA) was added to Zone 13.
- Per Docket ER22-424, Assembly Solar III (DEMO) was added to Zone 13.
- Per Docket ER21-1794, White Oak Wind’s (FPLP) Revenue Required was updated in Zone 3A.
- Per Docket ER21-666, Bishop Hill III's (WPPI) Revenue Requirement was updated in Zone 3A.
- Per Docket ER20-2541, J. Wayne Leonard Power Station's (ELMP) Revenue Requirement was updated in Zone 29.
- The MISO Schedule 2 rate increased by 1.85%
These changes are effective February 1, 2022.
January 1, 2022:
Rate changes were processed to incorporate the annual revenue requirements and/or divisor updates of Attachments O/GG/MM/ZZ for Transmission Owners using Forward looking Attachment O.
Rate changes were processed for the following items:
- Schedule 1
- Updated Schedule 1 expense amounts, including 2020 True-Ups. Updated divisors from the Attachment Os.
- The MISO average rate increased 2.39%.
- Schedule 2
- Per Docket ER21-2892, Prairie Wolf Solar (PWLP) was added to Zone 3A.
- Per Docket ER20-1662, Crystal Lake Wind I (FPLP) Revenue Requirement was updated in Zone 1.
- Per Docket ER20-2543, Crystal Lake Wind II (FPLP) Revenue Requirement was updated in Zone 1.
- Per Docket ER20-2222, Crystal Lake Wind III (FPLP) Revenue Requirement was updated in Zone 1.
- Teche Unit 3 (CPWR) was removed from Zone 32. Their suspension was effective on 12/31/2021.
- Burlington (ALTW) was removed from Zone 1. Their suspension was effective on 1/1/2022.
- Per Docket ER13-1589, RockGen Energy Units 1, 2 and 3 had an ownership change from TNSK to DPCM in Zone 2C.
- The MISO Schedule 2 rate increased by .06%
- Schedules 7, 8 & 9
- Annual Rate update for forward-looking TOs, including the 2020 True-ups. Updated divisors from the Attachment Os and Annual update of the Entergy-only RTOR (Regional Through & Out Rate - year 9 of a 10 year phase-in).
- MISO Average rate increased by 3.91%.
- Schedules 26, 37 & 38
- Updated Attachment GG revenue requirements for forward-looking TOs, including 2020 True-Ups. Updated divisors from the Attachment Os. This is also year 9 of a 13 year phase-in of the Entergy-only RTOR average rate being charged on transactions exiting the MISO South system. Newly approved MTEP20 projects added.
- The MISO average rate increase of 5.55%.
- Schedules 26-A and 39
- Annual update for forward-looking Transmission Owners
- The overall Revenue Requirement decreased by .93%.
- Schedules 26-C
- Cost recovery for TMEPs (Targeted Market Efficiency Projects) to reflect updates from MISO. Added a new Transmission Owner, AMIL.
- The overall Revenue Requirement increased by 5.92%.
- Schedules 26-D
- Cost recovery for TMEPs (Targeted Market Efficiency Projects) to reflect updates from PJM.
- The overall Revenue Requirement increased by 18.45%.
- Schedules 26-E
- New Schedule added for cost recovery for IMEPs (Interregional Market Efficiency Projects) to reflects updates for NIPSCO.
- The overall Revenue Requirement increased by 100%.
- Schedules 33
- Updated the divisors for the forward-looking Transmission Owners as part of the January Rate Update.
- The MISO system average rate decreased by .73%
- Schedules 45
- Annual update for forward-looking transmission owners. Updated divisors from the Attachment Os.
- MISO rate decreased by 5.71%
- Manitoba Hydro
- Schedule 1: Revised rates provided by MHEB for 2022, with a 8.13% increase from 2021.
- Schedule 2: Revised rates provided by MHEB for 2022, with a 8.13% increase from 2021.
- Schedule 7: Revised rates provided by MHEB for 2022 with a 8.13% increase from 2021.
- Schedule 8: Revised rates provided by MHEB for 2022 with a 8.13% increase from 2021.
These changes are effective January 1, 2022.
December 1, 2021:
Rate changes were processed for the following items:
- Schedule 2
- Per Docket ER21-2695, Lincoln Land 1 and 2 (LLW) was added to Zone 3A.
- Per Docket ER21-2968, Kuester 1-7 (UMRC) was added to Zone 2D.
- Per Docket ER21-2968, Mihm 1-3 (UMRC) was added to Zone 2E.
- The MISO Schedule 2 rate decreased by 2.28%.
These changes are effective December 1, 2021
November 1, 2021:
Rate changes were processed for the following items:
- Schedule 2
- Per Docket ER21-1005 Miles City, Glendive 1, Glendive 2, Lewis and Clark 2, Glen Ullin CS6, Diamond Willow, Cedar Hills and Thunder Spirit (MDUM) their interim rates were added to Zone 15.
- Per Docket ER21-1005, Big Stone and Coyote (MDUM) their interim rates were added to Zone 18.
- The MISO Schedule 2 rate decreased by .48%.
These changes are effective November 1, 2021
October 1, 2021:
Rate changes were processed for the following items:
- Schedule 2
- Per Docket ER21-2521, Broadlands Wind (BRDL) was added to Zone 3A.
- Per Docket ER20-1906 Story County Wind, LLC's (FPLP) Revenue Requirement was updated in Zone 1.
- Per Docket ER21-2348 Belle River Units 1 and 2 (MPPA) Revenue Requirement was updated in Zone 10.
- Per Docket ER21-2934/EL17-14 upon the sale of the generator Hardin County (ETEC) to ETI. Hardin was removed from Zone 31.
- Per Docket ER21-2971 Schahfer Unit 14 and Unit 15 (NIPS) were removed from Zone 17. Their retirement was approved for 10/1/2021.
- The MISO Schedule 2 rate decreased by .81%.
These changes are effective October 1, 2021
September 1, 2021:
Rate changes were processed for the following items:
- Schedule 2
- Per Docket ER21-2179, Oliver Wind I (FPLP) was added to Zone 14.
- Per Docket ER21-2401 Oliver Wind II (FPLP) was added to Zone 14.
- The MISO Schedule 2 rate increased by .30%.
These changes are effective September 1, 2021
August 1, 2021:
Rate changes were processed for the following items:
- Schedule 2
- Per Docket ER21-223 Audrain Power Plant, Callaway Nuclear Plant, Fairgrounds Power Plant, Keokuk Plant, Labadie Plant, Meramec Plant, Mexico Power Plant, Moberly Power Plant, Moreau Power Plant, Osage Plant, Peno Creek Power Plant, Rush Island Plant, Sioux Plant, Taum Sauk Plant, Venice Power Station (AMMO) were adjusted so their Revenue Requirement reflected the 10.02 ROE in Zone 3B. Goose Creek Power Plant, Kinmundy Power Plant, Pinckneyville Power Plant and Raccoon Creek Power Plant (AMIL) were also adjusted so their Revenue Requirement reflected the 10.02 ROE in Zone 3A.
- The MISO Schedule 2 rate decreased by .85%.
These changes are effective August 1, 2021
July 1, 2021:
Rate changes were processed for the following items:
- Schedule 2
- Per Docket ER21-1794 White Oak Wind (FPLP) was added to Zone 3A..
- Per Docket ER21-1662 Georgetown GT 1, Georgetown GT 4, Harding Street GT 1, Harding Street GT 2, Harding Street GT 4, Harding Street GT 5, Harding Street GT 6, Harding Street Steam 5, Harding Street Steam 6, Harding Street Steam 7, Petersburg Steam 2, Petersburg Steam 3 and Petersburg Steam 4 (IPL) were added to Zone 11.
- Per Docket ER 21-1622 Ashtabula 1 Wind, Astoria Station, Big Stone Plant, Coyote Station, Jamestown Units 1 and 2, Lake Preston, Langdon Wind, Luverne Wind, and Solway (OTP) were added to Zone 18. Merricourt Wind Energy Center (OTP) was added to Zone 15.
- Per the Attachment Y Grand Tower (SIGC) was removed from Zone 3A with a suspension date effective July 1, 2021.
- The MISO Schedule 2 rate increased by 2.01%.
These changes are effective July 1, 2021
June 1, 2021:
Rate changes were processed for the following items:
- Schedule 1
- Updated Schedule 1 expense amounts for Historical Transmission Owners. Updated divisors from the Attachment Os.
- The MISO average rate increased 4.64%.
- Schedule 2
- Per Docket ER21-1339 California Ridge Wind Energy, LLC (CALR) was added to Zone 3A.
- Per the Attachment Y, in Docket ER21-1559, Gallagher Units 2 and 4 (PSI) were removed from Zone 5 with a retirement date of June 1, 2021.
- Per the Attachment Y, in Docket ER21-1546, River Rouge 3 (DEMO) was removed from Zone 10 with a suspension date of June 1, 2021.
- Per the Attachment Y, schedule 2 Generator, Genoa Unit 3 (DPCM) was removed from Zone 26 with a retirement date of June 1, 2021.
- Per Docket ER21-1622, OTP’s stated rate was removed from rates in Zone 18. Once we receive the approved Generator Certification we will put the new generators in the next available month.
- The overall Schedule 2 rate increased by 2.66%.
- Schedules 7, 8 & 9
- Annual Rate Update for Historical Transmission Owners, Updated divisors from the Attachment Os.
- MISO Average rate increased by 8.74%.
- Schedules 26, 37 & 38
- Annual Rate Update for Historical Transmission Owners, Updated divisors from the Attachment Os.
- MISO Average rate increased by 3.47%.
- Schedules 26-A & 39
- Annual update for Historical Transmission Owners.
- The overall Revenue Requirement increased by 0.09%.
- Schedule 33
- Updated the divisors for the Historical Transmission Owners as part of the June Rate Update.
- The MISO system average rate increased by 3.50%
- Schedule 41
- Annual update for Historical Transmission Owners. Updated divisors from the Attachment Os.
- Entergy Arkansas recovery re-started to address final true-up.
- The overall Revenue Requirement increased by 6.17%.
- Schedule 42-B
- Annual update for Historical Transmission Owners. Updated divisors from the Attachment Os.
- Updated the divisors for the Historical Transmission Owners as part of the June Rate Update.
- The MISO system average rate decreased by 6.45%
- Schedule 45
- Updated the divisors for the Historical Transmission Owners as part of the June Rate Update.
- The MISO system average rate increased by 3.50%
These changes are effective June 1, 2021
May 1, 2021:
Rate changes were processed for the following items:
- Schedule 2
- Per Docket ER21-1046 Sugar Creek Wind One, LLC (TNSK) was added to Zone 3A.
- Per Docket EL21-37 Belle River Units 1 and 2 (MPPA) were added to Zone 10.
- The MISO Schedule 2 rate increased by 1.02%.
These changes are effective May 1, 2021
April 1, 2021:
Rate changes were processed for the following items:
- Schedule 2
- Per Docket ER21-1005 Miles City, Glendive 1, Glendive 2, Heskett 3, Lewis and Clark 2, Glen Ullin CS6, Diamond Willow, Cedar Hills and Thunder Spirit (MDUM) were added to Zone 15.
- Per Docket ER21-1005, Big Stone and Coyote (MDUM) were added to Zone 18.
- Per Docket ER19-2547, Pheasant run (DEMO) updated their Revenue Requirement in Zone 10.
- The MISO Schedule 2 rate decreased .80%.
These changes are effective April 1, 2021
March 1, 2021:
Rate changes were processed for the following items:
- Schedule 2
- Per Docket ER21-762, Bishop Hill Energy II (BHII) was added to Zone 3A.
- Per Docket ER21-666, Bishop Hill III (WPPI) was added to Zone 3A.
- The MISO Schedule 2 rate decreased .56%.
These changes are effective March 1, 2021
February 1, 2021:
Rate changes were processed for the following items:
- Schedule 2
- Per Docket ER21-953, Waterford Unit 1 (ELMP) was removed from Zone 29.
- The MISO Schedule 2 rate decreased .47%.
- Schedules 7, 8 & 9
- Per Docket ER20-108, an SPP filing, which approved additional MDU facilities to be included as Section 30.9 credits, affecting MDU's revenue credits on the Attachment O.
- MISO Average rate decreased by .03%.
- Schedule 33
- Per Docket ER21-370 a Blackstart unit will be added to Zone 32.
- MISO Schedule 33 increased by 2.51%.
These changes are effective February 1, 2021
January 1, 2021:
Rate changes were processed for the following items:
- Schedule 1
- Updated Schedule 1 expense amounts, including 2019 True-Ups.
- Updated divisors from the Attachment Os.
- The MISO average rate increased 7.42%.
- Schedule 2
- Per Docket ER20-2250, Choctaw County Generating Station (EMTO) was added to Zone 30.
- Per Docket's ER19-433 and ER21-223, Meramec CTG 2 (AMUE) was fully removed from rates in Zone 3B to reflect their retirement date of December 29, 2020..
- Schedule 2 fleet was transferred from Union Electric Company – Ameren Missouri (AMUE) to Ameren Missouri (AMMO) due to owners requesting to direct revenues to a different Market Participant, effective January 1, 2021.
- Schedule 2 generator, Garden Wind LLC, was transferred from Google Energy LLC (GOOG) to Nextera Energy Marketing, LLC (FPLP) due to owners requesting to direct revenues to a different Market Participant, effective January 1, 2021.
- Updated divisors from the Attachment Os.
- Overall, the MISO Schedule 2 rate increased 3.26%.
- Schedules 7, 8 & 9
- Annual Rate Update for forward-looking TOs, including the 2019 True-ups. Annual update of the Entergy-only RTOR (Regional Through & Out Rate – year 8 of a 10 Year phase-in).
- Updated divisors from the Attachment Os.
- MISO Average rate increased by 8.22%.
- Schedules 26, 37 & 38
- Updated Attachment GG revenue requirements for forward-looking TOs, including 2019 True-Ups. This is also year 8 of a 13 year phase-in of the Entergy-only RTOR average rate being charged on transactions exiting the MISO South system. Newly approved MTEP20 projects added.
- Updated divisors from the Attachment Os.
- The MISO average rate increase of 7.60%.
- Schedules 26-A & 39
- Annual update for forward-looking Transmission Owners.
- The overall Revenue Requirement increased by 1.98%.
- Schedule 26-C
- Cost recovery for TMEPs (Targeted Market Efficiency Projects) to reflect updates from MISO.
- The overall Revenue Requirement increased 79.57%.
- Schedule 26-D
- Cost recovery for TMEPs (Targeted Market Efficiency Projects) to reflect updates from PJM.
- The overall Revenue Requirement increased 21.22%.
- Schedule 33
- Updated the divisors for the forward-looking Transmission Owners as part of the January Rate Update.
- Updated divisors from the Attachment Os.
- The MISO system average rate increased by .99%
- Schedule 45
- Annual update for forward-looking transmission owners.
- Updated divisors from the Attachment Os.
- MISO rate decreased by 6.60%.
- Manitoba Hydro
- Schedule 1: Revised rates provided by MHEB for 2021, with a 7.25% decrease from 2020.
- Schedule 2: Revised rates provided by MHEB for 2021, with a 3.37% increase from 2020.
- Schedule 7: Revised rates provided by MHEB for 2021 with a .67% decrease from 2020.
- Schedule 8: Revised rates provided by MHEB for 2021 with a .14% decrease from 2020.
These changes are effective January 1, 2021
December 1, 2020:
Rate changes were processed for the following items:
- Schedule 2
- Meramec CTG 2 (AMUE) revenue requirement was prorated in Zone 3B to reflect their
retirement date of December 29, 2020. Meramec is being removed from rates per the
approval of their Attachment Y.
- Overall, the MISO Schedule 2 rate did not change.
These changes are effective December 1, 2020
November 1, 2020:
Rate changes were processed for the following items:
- Schedule 2
- Per Docket ER20-2589, Elm Road Generating Station (WPPI) was added to Zone 2D.
- Per Docket EL17-92, San Jacinto CT2 (ETEC) was added to Zone 31..
- Per Docket ER20-1062, Garden Wind, LLC. (GOOG) updated their Revenue Requirement in Zone 1..
- Per Docket ER20-2541, J Wayne Leonard Power Station (ELMP) was added to Zone 29.
- Per Docket ER20-2705, Mankato Energy Ctr 1 and Mankato Energy Ctr 2 changed ownership from MHLL to SWG in Zone 16.
- Overall, the MISO Schedule 2 rate increased by 2.81%./LI>
These changes are effective November 1, 2020
October 1, 2020:
Rate changes were processed for the following items:
- Schedule 1
- Per EC20-78, Consumers was authorized to directly sell their assets to METC, with the sale of their assets they no longer have Schedule 1 Expenses.
- The overall MISO rate decreased by 0.07%.
- Schedule 2
- Per Docket ER20-2543, Crystal Lake Wind II was added to zone 1 (ITCM)).
- Overall, the MISO Schedule 2 rate increased by 0.55%.
- Schedule 7, 8, 9
- Per EC20-78, Consumers was authorized to directly sell their assets to METC, with the sale of their transmission assets they no longer recover them from Attachment O.
- METC gained Consumer's assets in the transaction
- Overall the MISO Schedule 7,8,9 rate increased by .02%
- Schedule 26, 37, 38
- Per EC20-78 METC acquired Consumer’s transmission assets. METC’s gaining of Consumers transmission assets affects their Schedule 26 revenue requirement due to revised expense and return allocation factor decreases.
- Overall the MISO Schedule 26, 37 and 38 rate decreased by .02%.
- Schedule 26-A, 39
- Per EC20-78 METC acquired Consumer’s transmission assets. METC’s gaining of Consumers transmission assets affects their Schedule 26-A rate due to revised expense and return allocation factor decreases.
- Overall the METC Schedule 26-A, and 39 rate decreased by .06%.
These changes are effective October 1, 2020.
September 1, 2020:
Rate changes were processed for the following items:
- Schedule 1
- OTP Pricing zone added MRES load to account for service MRES is receiving. The OTP Pricing zone rate decreased 8.30% but the MISO-wide rate did not change as the Tariff states the Divisor will use the Schedules 7 and 8 Drive-Out and Drive-Through Rates.
- Schedule 2
- Per Docket ER20-2222, Crystal Lake Wind III was added to zone 1 (ITCM).
- Overall, the MISO Schedule 2 rate increased by 0.33%.
- Schedule 26C26D
- NIPSCO TMEP projects were updated to reflect the ROE change to 10.02%. This correction does not affect rates, just billing amounts with a 0.675% change in the monthly charge.
These changes are effective September 1, 2020.
August 1, 2020:
Rate changes were processed for the following items:
- Schedule 2
- Per Docket ER20-1691, the partial revenue requirement for AECC Bailey 1 was removed from Zone 28.
- Per Docket ER19-283, Allete replaced its generator specific revenue requirements with a fleet wide rate in Zone 14.
- Per Docket ER20-1662, Crystal Lake Wind Energy 1, LLC was added to Zone 1.
- Per Docket ER20-1906, Story County Wind, LLC was also added to Zone 1.
- Per Docket ER19-2546, the revenue requirement for Tuscola Wind II was reduced in Zone 10.
- Overall, the MISO Schedule 2 rate increased by 0.23%.
These changes are effective August 1, 2020.
July 1, 2020:
Rate changes were processed to incorporate a change in ROE per FERC Docket EL14-12
(Opinion 569A)
In addition, the following changes were made:
- Schedule 2 -
- Per Docket ER19-585, Quilt Block Wind Farm LLC was added to the ATC-WPL (2C) zone
- Per Docket ER19-1488, revenue requirements for SIGE units were reduced in the Vectren (23) zone
- Per Docket ER20-1691- revenue requirement for AECC’s Bailey unit was prorated due to retirement in the Entergy Arkansas (28) zone.
- Overall, the MISO Schedule 2 rate increased by 0.09%.
- Schedule 7, 8, & 9 – Per Docket ER20-1167, Republic Transmission LLC became a TO and is in the Vectren (23) zone. Republic Transmission LLC assets affect only Schedule 26.
- The overall impact on MISO system rates follows:
- • Schedule 2: 0.09% increase
- • Schedules 7, 8, & 9: 0.59% increase
- • Schedule 26: 2.06% decrease
- • Schedule 45: 0.06% decrease
- Schedule 42B – ROE change resulting in increased rates: EAI increase 0.60%; ELL increase 0.57%; EMI increase 0.56%; ETI increase 0.59%.
These changes are effective July 1, 2020.
June 1, 2020:
Rate changes were processed to incorporate the annual revenue requirements and/or divisor updates of Attachments O/GG/MM/ZZ for Transmission Owners using historical Attachment Os.
Rate changes were processed to incorporate the following:
- Schedule 2 - Divisors were updated for the June 2020 rate Update. In addition, the following changes were made:
- Per Docket ER20-1062, Garden Wind LLC was added to the ITCM (1) zone
- Per Docket ER20-6 the revenue requirement for Warrick Unit 4 (AGPT) was reduced in the Vectren (23) zone
- Per Docket ER20-1394 - Alliant’s Sheepskin and Rock River plants were retired in the ALTE (2) zone
- Overall, the MISO Schedule 2 rate increased by 0.26%.
- Schedule 41 - Annual Update Revenue Requirement and Divisors resulting in EAI rate change: (100.00%), ELL rate change: (100.00%), ETI rate change: 7.29%, ENO rate change: 12.60%. ELL and EAI reached full recovery of their Storm Securitization amounts resulting in a $0 rate going forward.
- Schedule 42B - Annual Update Revenue Requirement and Divisors, resulting in decreases: EAI rate change: (2.87%), ELL rate change: (5.17%), EMI rate change: (2.42%), ETI rate change: (10.28%).
- The overall impact on MISO system rates follows:
- • Schedule 1: 2.34% decrease
- • Schedule 2: 0.26% increase
- • Schedules 7, 8, & 9: 1.93% increase
- • Schedule 26: 0.37% decrease
- • Schedule 33: 0.04% increase
- • Schedule 45: 0.06% decrease
These changes are effective June 1, 2020.
May 1, 2020:
Rate changes were processed to incorporate the following:
- Schedule 2
- Per docket ER19-1368, the revenue requirement for Manitowoc Public Utilities was reduced in the ATC-WPS (28) zone.
- Per docket ER19-2224, the revenue requirement for Turtle Creek was reduced in the ITCM (1) zone.
- Per docket ER19-2235, the revenue requirement for Tuscola Bay Wind was reduced in the METC (13) zone.
- Overall, the MISO Schedule 2 rate decreased by 0.45%
These changes are effective May 1, 2020.
April 1, 2020:
Rate changes were processed to incorporate the following:
- Schedule 2
- Per docket ER20-569, the prorated revenue requirement for Sabine CoGen was removed from rates in Entergy TX TPZ.
- Per docket ER19-2029, Mankato Energy Center II was added to the NSP TPZ.
- Overall, the MISO Schedule 2 rate increased by 0.05%
These changes are effective April 1, 2020.
March 1, 2020:
Rate changes were processed to incorporate the following:
- Schedule 1
- Per Docket ER19-2050, GridLiance was added to AMIL TPZ.
- The overall MISO rate increased 0.36%.
- Schedule 2
- Per Docket ER20-569, the revenue requirement was prorated to account for its suspension for Sabine Cogen in the Entergy Texas (ETTO) pricing zone.
- Overall, the MISO Schedule 2 rate decreased by 0.12%
- Schedule 7,8,&9
- Per Docket ER20-2050, GridLiance was added to the AMIL TPZ.
- Overall, the MISO Schedule 7/8/9 rate increased by 0.10%
Note: The Pricing by Sink tab has changed integrating the format of the new billing system.
These changes are effective March 1, 2020.
February 1, 2020:
Rate changes were processed to incorporate the following:
- Schedule 2
- Per Docket ER19-1132, Cottonwood Tenant's Revenue Requirement was reduced, pending settlement proceedings.
- Per Dockets ER15-502, ER15-1136, and ER14-2080, revenue requirements were reduced for Bayou Cove, Big Cajun 1, and Big Cajun 2, respectively, pending settlement proceedings.
- Overall, the MISO Schedule 2 rate decreased by 0.79%
- Schedule 7,8 & 9
- Otter Tail Power incorporated the 9.88% ROE impact authorized in EL14-12 to the Docket ER20-176 - Attachment O corrections processed in January, 2020.
- The 5 Entergy Operating Companies (Arkansas, Louisiana, Mississippi, Texas, and New Orleans) removed Prepaid & Accrued Pension Cost & associated ADIT (Pension) from Rate Base impacts from their Attachment Os in compliance with the order issued in ER15-1436.
- Overall, the MISO Schedule 7/8/9 rate decreased by 0.12%
- Schedule 26,37,&38
- Otter Tail Power incorporated the 9.88% ROE impact authorized in EL14-12 to the Docket ER20-175 - Pre-2018 Error Corrections on Attachment GG corrections processed in January, 2020.
- Overall, the MISO Schedule 26 rate decrease was negligible.
These changes are effective February 1, 2020.
January 1 2020:
Rate changes were processed to incorporate the annual revenue requirements and/or divisor updates of Attachments O/GG/MM/ZZ for Transmission Owners (TOs) using a forward-looking Attachment O. This rate update also includes changing the MISO base ROE to 9.88% for all TOs. Manitoba Hydro (MHEB) provided revised rates for Schedules 1, 2, 7, 8, and 11.
In addition, these updates were also incorporated:
- Schedule 2
- Per Docket ER19-1488, AB Brown CT Units 3 and 4 were added to the Vectren/SIGE Transmission Pricing Zone (TPZ).
- Per Docket ER18-2280, the revenue requirement for Marshalltown Generating Station was reduce in the ITC Midwest TPZ.
- Schedule 7,8 & 9
- Per Docket ER20-175, OTP corrected a pre-2018 error which also affects Schedule 26.
- Per Docket ER20-176, OTP adds an adjustment line on Attachment O allowing prior year adjustments.
- Per Docket ER20-159, Pioneer is allowed recovery of pre-commercial costs
- Per Docket ER19-956, ITCM recognition of Intangible Assets as Transmission
- Per Docket EL14-12, reducing MISO base ROE to 9.88% for all MISO TOs including historical test year TOs.
- Schedule 26,37, & 38
- Newly approved MTEP19 projects added. This is also the second year of the phase-in of a portion (25.0%) of the MISO South (RTOR) average rate being charged on transactions exiting the MISO South system.
- Schedule 26-C & 26-D
- Cost recovery for TMEPs (Targeted Market Efficiency Projects) to reflect updates from MISO and PJM.
The overall impact on MISO system rates follows:
MISO MHEB
| Schedule 1: 0.83% decrease |
Schedule 1: 2.30% Increase |
| Schedule 2: 0.38% increase |
Schedule 2: 10.81% Decrease |
| Schedule 7,8,&9: 0.99% decrease |
Schedule 7: 8.06% Decrease |
| Schedule 26: 10.18% increase |
Schedule 8: 8.06% Decrease |
| Schedule 26A: 5.70% increase |
Schedule 11: 15.27% Increase |
| Schedule 33: 0.33% increase |
| Schedule 45: 6.27% increase |
These changes are effective January 1, 2020:.
December 1 2019:
Rate changes were processed to incorporate the following:
- Schedule 2
- Per Docket ER20-6, ALCOA’s Warrick Unit 4 was added to the SIGE pricing zone.
- Per Docket EL19-56, a generator specific revenue requirement replaced Hoosier Energy’s stated rate in the HE pricing zone.
- Per Docket ER19-2662, Vistra’s Duck Creek generator was retired in the AMIL zone.
- Per Docket EL 19-49, Cooperative Energy’s Batesville and Grand Gulf revenue requirements were reduced in the Entergy Mississippi pricing zone.
- Per Docket EL 19-49, Cooperative Energy’s Batesville and Grand Gulf revenue requirements were reduced in the Entergy Mississippi pricing zone.
Overall the MISO Schedule 2 rate decreased by 0.42%.
These changes are effective December 1, 2019.
November 1 2019:
Rate changes were processed to incorporate the following:
- Schedule 2
- Dynegy retired three units – Havana 6 and Hennepin per Docket ER19-2661 and Coffeen Power Station per Docket ER19-2662 all in the AMIL pricing zone.
- Mankato Energy Center’s Revenue Requirement was reduced per Docket ER19-2864 in the NSP pricing zone.
- Overall the MISO Schedule 2 rate decreased by 1.28%
These changes are effective November 1, 2019.
October 1 2019:
Rate changes were processed to incorporate the following:
- Schedule 2
- The ITC TPZ added two units, Docket ER19-2546 added Tuscola Wind II, Docket ER19-2547 added Pheasant Run Wind. Overall the MISO Schedule 2 rate increased by 0.61%.
- Schedules 7, 8, and 9
- Docket ER19-2516 added Breckenridge to the OTP zone.
- Docket EC19-83 resulted in the sale of Consumers transmission assets to METC. The overall MISO rate decreased (0.01%).
- Schedule 26
- Docket EC19-83 with the sale of Consumers transmission resulted in a redistribution of Schedule 26 rates. The overall MISO rate decreased (0.04%).
- Schedule 26-A
- Docket EC19-83 with the sale of Consumers transmission resulted in minor shifts in the annual revenue requirement.
These changes are effective October 1, 2019.
September 1 2019:
Rate changes were processed to incorporate the following:
- Schedule 2
- Docket ER13-1589, had a change in control moving from CALP (Calpine) to TNSK (Tenaska) with no change in revenue requirements. Alliant Energy changed the revenue recipient for its Marshalltown Generating Station from ALTM to ALTW with no change in revenue requirements. Per docket ER19-2235, Tuscola Bay Wind was added to the METC zone. Per docket ER19-2224, Turtle Creek Wind Farm was added to the ITCM zone. Overall the MISO Schedule 2 rate increased by 1.00%
- Schedules 7, 8, and 9
- WPPI templates were revised and approved in Docket ER19-2315 which increased the NSP zone 0.02%.
- East River Power Cooperative’s 30.9 Transmission Facilities were included in the NSP Pricing Zone with the template changes approved in Docket ER19-2295 which along with WPPI increased the NSP zone 0.02%.
- METC’s revised ADIT calculations were included and approved in Docket ER18-2323 which decreased the CONS zone 0.07%. These small changes had no overall impact on the MISO Through and Out Rate.
- Schedule 26
- WPPI templates were revised and approved in Docket ER19-2315 with no rate impact.
- METC’s ADIT calculations were revised and approved in Docket ER18-2323 with a 0.08% decrease.
- Schedule 26-A
- WPPI templates were revised and approved in Docket ER19-2315.
- METC’s revised ADIT calculations were included and approved in Docket ER18-2323. These two changes resulted in an annual revenue requirement increase of 0.01%.
These changes are effective September 1, 2019.
July 1 2019:
Rate changes were processed to incorporate the following changes related to the withdrawal and transfer of 38 MW of load and related transmission assets from MISO to the Southwest Power Pool (“ETEC Transaction”):
- Schedules 7,8 & 9
- Deep East Texas Electric Cooperative, Inc – partial withdrawal from MISO: transfer of transmission assets to SPP approved by FERC 6/14/19 (ER19-1541; parallel filing made by SPP in ER19-1137) – effective 7/1/19
- East Texas Electric Cooperative, Inc. (ETEC) – partial withdrawal from MISO: transfer of transmission assets to SPP approved by FERC 6/14/19 (ER19-1541; parallel filing made by SPP in ER19-1137) – effective 7/1/19
- Entergy Texas, LLC – revision to zonal load reported for the Entergy Texas pricing zone related to the ETEC Transaction
As a result of the changes above, divisors were also updated for the following Schedules with the associated rate impacts:
- Schedule 1 MISO 0.03%
- Schedule 2 MISO 0.03%
- Schedules 7, 8, & 9 MISO (0.02%)
- Schedules 26 MISO 0.03%
- Schedule 33 MISO 0.03%
- Schedule 45 MISO 0.04%
These changes are effective July 1, 2019.
June 1, 2019:
Rate changes were processed to incorporate the annual revenue requirements and/or divisor updates of Attachments O/GG/MM/ZZ for Transmission Owners using historical Attachment Os.
- Schedule 1 - Updated Schedule 1 Revenue Requirement and Divisor – Overall, the MISO Through and Out Rate change is: (0.09%)
- Schedule 2 - Divisors were updated for the June 2019 rate Update. In addition, the following changes were made:
- • Entergy Mississippi TPZ decreased 9.69% due to Rex Brown Unit #4 Retirement.
- • Big Rivers TPZ decreased 4.42% due to reduced revenue requirement of AMP’s Smithland Hydro generator.
- • Vectren’s TPZ increased 46.03% due to; 1) AMP's Cannelton Hydro generator reduced revenue requirements and 2) Replacing stated rates with generator-specific revenue requirements.
- • ATC_WPS TPZ decreased 0.66% due to reduced revenue requirement for Manitowoc Public Utilities.
- • Ameren Illinois TPZ decreased by 2.65% due to: 1) Duck Creek generator reduced revenue requirement, 2) the ED Edwards generator revenue requirement was reduced and split into ED Edwards 2 and ED Edwards 3, and 3) ED Edwards 3 generator reduced revenue requirement.
- • Overall, the MISO Schedule 2 rate decreased by 1.97%.
- Schedules 7,8 & 9 - Historical Test Year TOs - Revenue Requirement, Divisor, and CBM updates. AEP I & M integrated to DEI TPZ and added WVPA to the AMMO TPZ. Overall MISO Rate Change: 4.72%.
- Schedules 26, 37 & 38 - Historical TO ATRR and Divisor updates. Overall MISO Rate Change: (2.67%)
- Schedule 33 - Revenue requirements were modified per dockets ER18-1890 and ER19-934. Divisors were updated, and adjustments were made to revenue requirements for transactions exiting the system in 2018. The MISO system average rate decreased by 7.83%.
- Schedule 41 - Annual Update Revenue Requirement and Divisors resulting in decreases of: EAI rate change: (18.63%), ELL rate change: (3.52%), ETI rate change: (18.09%), ENO rate change: (34.11%).
- Schedule 42B - Annual Update Revenue Requirement and Divisors, resulting in decreases: EAI rate change: (8.01%), ELL rate change: (6.58%), EMI rate change: (7.21%), ETI rate change: (8.26%).
- Schedule 45 - Divisors updated. Overall MISO Rate Change: (2.14%)
- The overall impact on MISO system rates follows:
- • Schedule 1: 0.09% decrease
- • Schedule 2: 1.97% decrease
- • Schedules 7, 8, & 9: 4.72% increase
- • Schedule 26: 2.67% decrease
- • Schedule 33: 7.83% increase
- • Schedule 45: 2.14% decrease
These changes are effective June 1, 2019.
May 1, 2019:
Rate changes were processed to incorporate the following:
- Schedule 2
- - Per docket EL19-48, Prairie Power's Alsey Unit 6 generator was added to the Ameren TPZ, increasing the Schedule 2 rate by 0.23%. Per docket ER19-455, the Stoneray generator was added to the NSP TPZ, increasing the Schedule 2 rate by 3.18%. Additionally, Grand Gulf and Batesville generators were added to the Entergy Mississippi TPZ per docket EL19-49. The Schedule 2 rate in that zone increased by 44.99%. Overall, the MISO Schedule 2 rate increased by 1.03%.
These changes are effective May 1, 2019.
April 1, 2019:
Rate changes were processed to incorporate the following:
- Schedule 2
- -Per docket ER19-1471, the revenue requirement for Presque Isle was removed from the ATC-WEC TPZ, which decreased the ATC-WEC rate by 5.75%. Additionally, the revenue requirement for St. Clair 1 was removed from the ITC TPZ decreasing the zonal rate by 0.70% (no docket assigned). The MISO average Schedule 2 rate decreased by 0.29%.
These changes are effective April 1, 2019.
March 1, 2019:
Rate changes were processed to incorporate the following:
- Per docket ER19-776 Henderson added as a TO. MISO implemented rates March 1, 2019 with impacts to the following schedules and rates – Henderson is in the BREC pricing zone.
- Schedule 1 MISO rate decreased 0.09% BREC rate decreased 7.21%
- Schedule 7,8 & 9 MISO rate decreased 0.05% BREC rate decreased 1.33%
- Schedule 26 MISO rate decreased 0.09% BREC rate decreased 7.21%
- Schedule 33 MISO rate decreased 0.09% BREC rate not impacted
- Schedule 45 MISO rate decreased 0.09% BREC rate not impacted
- Schedule 2
- Per docket ER19-776 Henderson added as a TO effective 2/1/19 decreasing the BREC rate 7.21%. Per docket ER18-2280, Marshalltown Generating Station was added to the ITC Midwest TPZ, which increased the TPZ rate by 59.99%. Per docket ER18-1704, Stuttgart Solar's annual revenue requirement was reduced to $204,000, which decreased the Entergy Arkansas TPZ rate by 0.56%. Per docket ER18-1737, NIPSCO's fleet revenue requirement was reduced, resulting in a decrease of 5.00% in the NIPSCO TPZ rate. Per docket ER19-433, Union Electric's fleet revenue requirements were reduced, resulting in a decrease of 15.25% in the Ameren MO TPZ rate and a decrease of 3.78% in the Ameren IL TPZ rate. Additionally, NERC IDs were changed from NRG to CCJN for Big Cajun 1, Big Cajun 2, and Bayou Cove generators. There were no changes to existing revenue requirements for these generators. The MISO average Schedule 2 rate decreased by 0.77%.
These changes are effective March 1, 2019.
February 22, 2019:
Rate changes were processed to incorporate the following:
- Schedule 2
- Rail Splitter Wind Farm was added to the AMIL TPZ per docket ER18-2487, which increased the AMIL rate by 2.31%. Per docket ER17-1730 Revenue Requirements for Entergy's four Union Station generators were reduced to a total of $4,300,000, which reduced the overall Entergy Arkansas TPZ rate by 9.93%. Minnesota Power updated its stated rate to generator-specific revenue requirements per docket ER19-283, which increased the MP TPZ rate 175.08%. Big Rivers HMPL Unit 2 was retired effective 2/1/2019, which decreased the BREC TPZ rate by 5.01% (no docket assigned). Overall the MISO average Schedule 2 rate increased by 0.77%.
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).
- Schedule 2
- Order ER18-829 revised the Revenue Requirement in the ALTE TPZ resulting in a 32.15% decrease. Order ER18-829 also revised the Revenue Requirement in the WEC TPZ resulting in a 19.68% decrease. ELMP's Sterlington 7 generator was retired, effective 1/1/2019, per ER19-709 resulting in the Entergy Louisiana TPZ rate decreasing by 0.45%. MISO’s average Sch. 2 rates decreased 2.15%.
- Schedules 7,8 & 9
- Other changes included Income Tax calc changes for AMIL/ATXI (ER17-2323) and GRE/MDU/MEC/MP/NIPSCO/NSP/OTP/Vectren (ER19-249). ADIT (Accumulated Deferred Income Taxes) ratebase changes for MP/MDU/NIPSCO/OTP/Vectren (ER18-1739), AMIL/ATXI/NSP (ER18-2322), and ITC/ITCM (ER18-2323). MISO Average rate increased by 5.50%.
- Schedule 26, 37, & 38
- Newly approved MTEP18 projects added. This is also the first year of the phase-in of a portion (12.5%) of the MISO average rate being charged on transactions exiting the MISO South system. The MISO Average rate decreased 0.25%.
- Schedule 26A & 39
- Also added a 50 BP ROE Adder for ATXI associated with the Mark Twain project (ER18-463). The overall Revenue Requirement increased by 12.62%.
- Schedule 26C
- Cost recovery for TMEPs (Targeted Market Efficiency Projects) approved in Docket No. ER18-867 effective 4/17/18.
- Schedule 26D
- Cost recovery for TMEPs (Targeted Market Efficiency Projects) approved in Docket No. ER18-867 effective 4/17/18. Initial ATRR to bill / collect.
- Manitoba Hydro (MHEB) provided revised rates for Schedules 1, 2, 7, 8, and 11.
- The overall impact on MISO system rates follows:
- Schedule 1: 2.49% decrease
- Schedule 2: 2.15% decrease
- Schedules 7, 8, & 9: 5.50% increase
- Schedule 26: 0.25% decrease
- Schedule 26A: 12.62% increase
- Schedule 33: 0.23% increase
- Schedule 45: 49.69% increase
- These changes are effective January 1, 2019.
December 1, 2018:
Rate changes were processed to incorporate the following:
- Schedule 2
- Ameren Missouri suspended the Meramec CT1 generator reducing the Revenue Requirement by $86,876 to $79,873 in docket ER19-433. The Ameren Missouri pricing zone rate decreased by 0.4523% with the MISO average Schedule 2 rate decreasing by 0.0422%.
These changes are effective December 1, 2018.
November 18, 2018:
Rate changes were processed to incorporate the following:
- Schedule 2
- WPS removed its Stated Rate and replaced it with generator specific revenue requirements per Docket ER18-2115. This addition of several generators resulted in a MISO average Schedule 2 rate increase of 1.64%
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;
- Schedule 7, 8, & 9 resulting in a decrease of 0.24%
- Schedule 26 resulting in a decrease of 0.30%
- Schedule 26-A resulting in a decrease of 0.30%
These changes are effective November 1, 2018.
October 18, 2018:
Rate changes were processed to incorporate the following:
- Schedules 2
- AECS retired Edgewater 4 from the ATC-WPL zone per docket ER18-2069.
- Reduced the revenue requirements for Carville GT1, Carville GT2, and Carville ST in the Entergy Louisiana TPZ. The Interim Implementation of their Settlement Agreement was approved in Docket ER18-554.
- Added Stuttgart Solar generator located in the Entergy Arkansas Transmission Pricing Zone per Docket ER18-1704.
- Increased the revenue requirement for the NIPSCO Sch. 2 fleet refresh per Docket ER18-1737.
- MISO system-wide rates decreased 0.03%.
These changes are effective October 1, 2018.
September 19, 2018:
Rate changes were processed to incorporate the following:
- Schedules 2
- Added Cannelton Hydro generator located in the Vectren Transmission Pricing Zone per Docket EL18-172.
- Added Smithland Hydro generator located in the Big Rivers Transmission Pricing Zone per Docket EL18-174.
- Added Stuttgart Solar generator located in the Entergy Arkansas Transmission Pricing Zone per Docket ER18-1704.
- Reduced the revenue requirement for the RockGen facility in the ATC-WPL Transmission Pricing Zone per Docket EL18-51/ER13-1589.
- Reduced the revenue requirement for the Settler’s Trail Wind Farm in the Ameren Illinois Transmission Pricing Zone per Docket ER18-642.
- Reduced the revenue requirement for the Pioneer Trail Wind Farm in the Ameren Illinois Transmission Pricing Zone per Docket ER18-1473.
- MISO system-wide rates increased 0.72%.
- Schedule 26-A
- Added Pioneer Transmission as a new Transmission Owner and participant in MVP Project 2202. Their tariff changes were approved in Docket ER18-1159. We are implementing their 2018 projection.
- The MISO Sch. 26-A revenue requirement increased 2.08%.
These changes are effective September 1, 2018.
August 16, 2018:
Rate changes were processed to incorporate the following:
- Schedules 2
- Added Pioneer Trail Wind Farm generator located in the Ameren Illinois Transmission Pricing Zone per Docket ER18-1473.
- MISO system-wide rates increased 0.41%.
These changes are effective August 1, 2018.
July 19, 2018:
Rate changes were processed to incorporate the following:
- Schedules 7, 8, 9
- Added Hoosier Energy’s Transmission Assets located in the Ameren Illinois zone per Docket ER18-1380.
- MISO system-wide rates increased 0.04%.
- Schedule 33
- Per docket ER12-2678, WEC’s revenue requirement was decreased for all Blackstart facilities in the ATC service area.
- MISO system-wide rates decreased 31.73%.
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:
- Schedule 2
- In the ATC-WEC TPZ, generator-specific revenue requirements were approved for 8 generators in Docket ER18-829.
- In the ATC-WPL TPZ, the Glacier Hills generator was also approved in Docket ER18-829.
- In the ITCM TPZ, the ML Kapp and Red Cedar generators were retired as addressed in Docket ER18-1250
- In the NIPSCO TPZ, Bailly Units 7 & 8 were retired as addressed in Docket ER18-1242.
- In the Duke Indiana TPZ, the Connersville and Miami Wabash units were retired as addressed in Docket ER18-1196.
- In the Entergy Mississippi TPZ, the Baxter-Wilson #2 and Rex Brown #3 units were retired as addressed in Docket ER18-1703.
- In the NSP TPZ, the Red Pine Wind generators' revenue requirement was reduced per the settlement in Docket ER18-563.
The overall impact on MISO system rates follows:
- Schedule 1: 1.46% increase
- Schedule 2: 1.91% increase
- Schedules 7, 8, & 9: 2.66% decrease
- Schedule 26: 0.01% increase
- Schedule 33: 0.25% increase
- Schedule 45: 0.25% increase
These changes are effective June 1, 2018.
May 22, 2018:
Rate changes were processed to incorporate the following:
- Schedule 2
- In the AMIL TPZ interim revenue requirements were approved for the Tilton generator in Docket ER14-1428.
- In the ITC TPZ, revenue requirements for DTE were finalized as part of an approved Settlement in Docket ER17-1414.
- In the Entergy Arkansas TPZ, interim revenue requirements were approved for the City of Jonesboro generators in Docket EL18-36
- MISO system-wide rates decreased 1.73%.
These changes are effective May 1, 2018.
April 23, 2018:
Rate changes were processed to incorporate the following:
- Schedule 2
- In the AMIL TPZ interim rates were approved for Settler's Trail Wind Farm in Docket ER18-642.
- In the GRE TPZ interim rates were approved for GRE in Docket EL17-33.
- MISO system-wide rates decreased 0.08%.
- Schedules 7, 8, & 9
- NSP submitted a correction to their 2018 gross plant amount reported in the GRE pricing zone, which resulted in a revenue requirement shift of $740,341 between the zones.
- MISO system-wide rates changed 0.00%.
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:
- Allete, Inc. dba Minnesota Power (MP)
- Ameren Illinois Company (AIC)
- American Transmission Company (ATC)
- Ameren Transmission Company of Illinois (ATXI)
- International Transmission Company (ITC)
- ITC Midwest (ITCM)
- Montana-Dakota Utilities (MDU)
- MidAmerican Energy Company (MEC)
- Michigan Electric Transmission Company (METC)
- Northern Indiana Public Service Company (NIPS)
- NSP Companies (NSP)
- Otter Tail Power Company (OTP)
- Vectren Energy
Additional changes reflected in the update include the following:
- Schedule 2
- In the NSP TPZ, interim rates were approved for Red Pine Wind in Docket ER18-563.
- In the ELTO TPZ, interim rates were approved for Carville GT1, GT2, & ST in Docket ER18-554.
The following schedules changed: 2, 7, 8, 9, 26, 26-A, 37, 38, and 45.
The overall impact on MISO system rates follows:
- Schedule 2: 1.21% increase
- Schedules 7, 8, & 9: 5.09% decrease
- Schedule 26: 7.48% decrease
- Schedule 45: 17.22% decrease
These changes are effective March 1, 2018.
February 23, 2018:
Rate changes were processed to incorporate the following:
- Schedule 2
- In the EATO TPZ, interim rates were approved for City of Jonesboro Units A through E in Docket EL18-36.
- MISO system-wide rates increased 0.18%.
- Schedules 7, 8, & 9
- Implemented the 50 Basis Point RTO Membership Adder for Detroit Lakes Public Utilities, Hutchinson Utilities Commission, ALP Utilities, Benson Municipal Utilities, and Worthington Public Utilities per ER15-1067.
- These changes affected rates in the ITCM, Otter Tail, and Great River Energy zones.
- MISO system-wide rates changed 0.00%
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:
- Schedule 2
- In the ATC-WPL TPZ, ATC-WEC TPZ and ITCM TPZ revised revenue requirements were incorporated from the Settlement Agreement in EL17-60.
- In the AMMO TPZ, the Kirksville unit retired effective 1/1/18 (ER18-473).
- In the GRE TPZ, revised revenue requirements were implemented, and new generators were added from the interim order in EL17-33.
- Schedules 7, 8, & 9
- Annual update of the Entergy-only RTOR (EL14-19-002)
- Cedar Falls Utilities (CFU) transitioned from utilizing a historical test period to forward-looking formula rate effective 01/01/18 (ER18-94)
- Central Power Electric Cooperative (CPEC) – updated Attachment O to reflect asset sale to Montana-Dakota Utilities (MDU) & subsequent removal of related 30.9 credits in the MDU pricing zone.
- Schedule 26—newly approved MTEP17 projects added
- Schedule 42A terminated – full recovery achieved in Entergy Louisiana pricing zone, rate reduced to zero
- Manitoba Hydro (MHEB) provided revised rates for Schedules 1, 2, 7, 8, and 11.
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:
- Schedule 1: 3.18% decrease
- Schedule 2: 0.50% decrease
- Schedules 7, 8, & 9: 2.45% increase
- Schedule 26: 0.72% decrease
- Schedule 33: 0.10% increase
- Schedule 45: 10.93% decrease
These changes are effective January 1, 2018.
December 11, 2017:
Rate changes were processed to incorporate the following:
- Schedule 2
- In AMIL TPZ, the Tilton facility changed NERC IDs due to an upstream ownership change. EAGL was changed to TILT.
- There is no change to the revenue requirement/rates from this action (FERC Docket ER17-1428).
- In the CLECO TPZ, all of CLECO's units had their revenue requirement reduced from the Interim Implementation of a Settlement Agreement in Docket ER17-1518.
- MISO system-wide rates decreased 0.29%.
These changes are effective December 1, 2017.
November 17, 2017:
Rate changes were processed to incorporate the following:
- Schedule 2
- In ITCM TPZ, AECS Fox Lake and Centerville units retired effective 11/1/17 per FERC Docket ER17-2409.
- In ITC TPZ, DTE St. Clair 4 is retired effective 11/1/17 per FERC Docket EL18-23.
- MISO system-wide rates decreased 0.13%.
These changes are effective November 1, 2017.
October 19, 2017:
Rate changes were processed to incorporate the following:
- Schedule 2
- In CLECO TPZ, interim rates were approved for City of Alexandria, LA Hunter 5-11 in docket EL17-80.
- MISO system-wide rates increased 0.23%.
- Schedules 7/8/9
- Cam-Wal Electric Cooperative integrated as a new 30.9 customer in the MDU pricing zone.
- MISO system-wide rates changed 0.00%.
These changes are effective October 1, 2017.
September 20, 2017:
Rate changes were processed to incorporate the following::
- Schedule 2
- In EATO TPZ, initial rates approved for Big Cajun II Unit 3 per Docket ER17-1731.
- In ITCM TPZ, AECS retired Grinnell CT1 & CT2 per Docket ER17-2085.
- MISO system-wide rates increased 0.14%.
These changes are effective September 1, 2017.
Augest 18, 2017:
Rate changes were processed to incorporate the following::
- Schedule 2
- In EATO TPZ, initial rates approved for Union Power Station per Docket ER17-1730.
- MISO system-wide rates increased 3.10%
- Schedules 7, 8, & 9
- Incorporated changes to MRES’s Attachment O approved in ER17-1515
- MISO system-wide rates increased 0.01%.
- Schedules 26, 37, & 38
- MRES’s Attachment GG was updated to reflect Att. O changes approved in ER17-1515
- MISO system-wide rates increased 0.18%
- Schedule 26-A
- MRES’s Attachment MM was updated to reflect Att. O changes approved in ER17-1515
These changes are effective August 1, 2017.
July 25, 2017:
Rate changes were processed to incorporate the following::
- Schedule 2
- In ELTO TPZ, settlement was reached for Ninemile #6 in Docket ER16-1832, effective 12/1/2016.
- In CLECO TPZ, Cleco implemented interim rates per Docket ER17-1518, effective 7/1/2017.
- MISO system-wide rates increased 1.01%.
- Schedules 7, 8, & 9
- Incorporated changes to WPPI's Attachment O approved in ER17-1504.
- No change to MISO system-wide rates.
- Schedule 26
- WPPI's Attachment GG was updated to reflect Att. O changes approved in ER17-1504.
- MISO sytem-wide rates increased 0.07%.
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:
- Schedule 2
- In ITC TPZ, DTE decreased revenue requirement due to initial order per Docket EL17-71.
- In ETTO TPZ, Sabine Cogen decreased revenue requirement due to approved settlement agreement per Docket ER17-210.
- In ETTO TPZ, Hardin County and San Jacinto were added per Docket EL17-14, effective 6/1/17.
- In ELTO TPZ, Nelson 4 suspended due to forced outage starting 6/1/17 through 6/1/20.
- In AMIL TPZ, ownership of Lively Grove E.P. transferred to Wabash Valley Power Association per Docket ER17-1375.
- In AMIL TPZ, interim implementation of settlement rates associated with the retirement of Newton #2, per Docket ER17-1648, effective 6/1/17.
- MISO system-wide rates decreased 0.92%.
- Schedules 7, 8, & 9
- Inclusion in the MDU pricing zone of 30.9 customers, East River Electric Power Cooperative and Upper Missouri Power Cooperative.
- MISO system-wide rates decreased 0.66%.
- Schedule 26-A
- Cedar Falls Utilities was included for the first time.
- Schedule 33
- AECS-IPL had certain blackstart resources undergo fuel supply changes and modified the blackstart rate schedule pursuant to ER16-2294, effective 9/1/16.
- MISO system-wide rates decreased 0.89%.
- Schedule 41
- Entergy New Orleans was included per ER17-273 issued 12/19/2016.
These changes are effective June 1, 2017.
May 24, 2017:
Rate changes were processed to incorporate the following:
- Schedule 1
- Updated load values to reflect addition of new 30.9 customer (CPEC) in the OTP pricing
- MISO system-wide rates decreased by 0.07%
- Schedule 2
- In ITCM TPZ, ALTW decreased revenue requirement offset by the addition of Emery due to interim rates implemented from Docket ER17-980 effective 5/1/17
- In ALTE TPZ, ALTE increased revenue requirement due to interim rates implemented from Docket ER17-980 effective 5/1/17
- In WEC TPZ, ALTM added interim rates for Neenah and Sheboygan Falls implemented from Docket ER17-980 effective 5/1/17
- Updated load values to reflect addition of new 30.9 customer (CPEC) in the OTP pricing zone
- MISO system-wide rates increased by 0.97%
- Schedules 7,8,9
- Central Power Electric Cooperative (CPEC) integrated as a new 30.9 customer in the following zones:
- Montana Dakota Utilities (MDU) – adjustment to revenue requirement
- Otter Tail Power Company (OTP) – adjustments to revenue requirement & load. OTP’s 30.9 procedures were filed and accepted in ER17-1014, effective May 1, 2017.
- MISO system-wide rates decreased 0.02%
- Schedule 26
- Updated load values to reflect addition of new 30.9 customer (CPEC) in the OTP pricing zone
- MISO system-wide rates decreased 0.07%
- Schedule 33
- Updated load values to reflect addition of new 30.9 customer (CPEC) in the OTP pricing zone
- MISO system-wide rates decreased 0.07%
- Schedule 42A
- Entergy Arkansas pricing zone – full recovery achieved, rate reduced to zero
- Entergy Louisiana pricing zone – billing restarted to achieve full recovery
- Entergy Mississippi pricing zone – full recovery achieved, rate reduced to zero
- Entergy Texas pricing zone – full recovery achieved, rate reduced to zero
- Schedule 45
- Updated load values to reflect addition of new 30.9 customer (CPEC) in the OTP pricing zone
- MISO system-wide rates decreased 0.09%
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:
- Schedule 7,8, & 9
- RTO Adder implementation for Deep East Texas Electric Cooperative, Jasper-Newton Electric Cooperative, and Sam Houston Electric Cooperative per ER17-893.
- GRE - correction to 2015 true-up adjustment calculation to remove Willmar values from the projected rate used in the calculation of the true-up.
- Entergy-only RTOR calculation - DEMCO joined as a 30.9 customer of Entergy LA in February 2017 and their revenue requirement was erroneously included in the Entergy-only RTOR calculation on the 'MISO' tab.
The overall impact on MISO system rates follows:
- Schedules 7, 8, & 9: 0.01% decrease
- Schedule 26: 0.01% decrease
- Schedule 45: 0.51% increase
These changes are effective April 1, 2017.
March 15, 2017:
Rate changes were processed to incorporate the following:
- Schedule 2
- In the ITCM zone, LWP Lessee, LLC's Revenue Requirement was reduced per the terms of the Settlement Agreement in Docket ER16-1923.
- MISO system-wide rates decreased by 0.53%
- Schedules 7, 8, & 9
- Great River Energy submitted an Attachment O correction of their Transmission Depreciation Expense.
- MISO system-wide rates decreased 0.14%.
These changes are effective March 1, 2017.
February 17, 2017:
Rate changes were processed to incorporate the following:
- Schedule 2
- Calpine Energy Services L.P. (CALP)transferred its Schedule 2 revenue requirement to Southern Company Services,Inc. (SWE) for the Mankato Energy Center in the NSP TPZ.
- No impact on rates.
- Schedules 7, 8, & 9
- East Texas Electric Cooperative, Inc (ETEC)was integrated into rates as a new Transmission Owner in the Entergy TexasPricing Zone.
- Dixie Electric Membership Corporation (DEMCO)was added as a 30.9 customer in the Entergy Louisiana Pricing Zone.
- Added Dairyland’s RTO adder per docketER17-529.
- MISO system-wide rates increased 0.09%.
- Schedule 26
- Added Dairyland’s RTO adder per docketER17-529.
- MISO system-widerates changed 0.00%.
- Schedule 33
- Added revenue requirement to METC Zone for Consumers Energy Company (Thetford 2, 3 &4 and Ludington 2, 3 & 5) pursuant to ER16-2669.
- MISO system-wide rates increased by 11.3%.
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:
- Schedule 2
- In the METC Pricing Zone, Consumers Energy reduced the revenue requirements for severalgenerators (ER16-1058 & EL16-56). The METC Pricing Zone rates decreased by 4.98%.
- In the Entergy Texas Pricing Zone, Sabine Cogen’s revenue requirement was added(ER17-210). The Entergy Texas Pricing Zone rates increased by 5.25%.
- Schedules 7, 8, & 9
- Entergy-only RTOR annual rate update (EL14-19-002)
- Tex-La RTO Adder implementation (ER17-265)
- Schedule 26—thirteen new MTEP16 projects were added
- Schedule 41 – updated to include securitization costs arising from Hurricane Isaac (ER17-273). The Entergy Louisiana Pricing Zone rates increased by 9.86%.
- South Mississippi Electric Power Association (SMEPA) – name change to Cooperative Energy (ER17-755)
- Manitoba Hydro (MHEB) provided revised rates for Schedules 1, 2, 7, 8, and 11.
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:
- Schedule 1: 2.86% decrease
- Schedule 2: 0.35% decrease
- Schedules 7, 8, & 9: 5.37% increase
- Schedule 26: 5.2% increase
- Schedule 33: .25% decrease
- Schedule 45: 32.98% decrease
These changes are effective January 1, 2017.
December 6, 2016:
Rate changes were processed to incorporate the following:
- Schedule 2
- In the Entergy Louisiana Pricing Zone, an interim rate was added for Ninemile Units 6A, 6B, & 6C per Docket ER16-1832 effective 12/1/16. The Entergy Louisiana Pricing Zones rates increased by 9.52%.
- In the Duke Indiana Pricing Zone, Duke Indiana corrected the revenue requirement for Markland Unit 3 per Docket ER16-200. The Duke Indiana Pricing Zones rates increased by 0.0115%.
- MISO average Schedule 2 rates increased by 1.15%.
These changes are effective December 1, 2016.
November 16, 2016:
Rate changes were processed to incorporate the following:
- Schedule 2
- In AMIL TPZ, Dynegy has suspended Newton Unit 2 effective 9/15/16 with the decommissioning and retirement effective 11/29/16 (ER16-2422).
- AMIL TPZ rates decreased by 3.327%.
- Also in AMIL TPZ, Dynegy has suspended Baldwin Unit 3 effective 10/17/16 (ER16-2566).
- AMIL TPZ rates decreased by an additional 1.893%.
- MISO average schedule 2 rates decreased by 0.6705%.
These changes are effective November 1, 2016.
October 25, 2016:
Rate changes were processed to incorporate the following:
- Schedule 1
- Corrected the load values in the Entergy Mississippi zone. Entergy Mississippi is reporting SMEPA's load. Entergy Mississippi TPZ decreased by 0.21%.
- Overall MISO Rate Change: (.01%)
- Schedule 2
- In METC TPZ, Reduced the revenue requirements for Wolverine Burnips, Hersey, Vestaburg, & Alpine Units 1 & 2 due to final settlement agreement of Docket ER16-1036. METC TPZ rates decreased by 2.5%.
- In Cinergy JTS TPZ, interim rates for WVPA Gibson Unit 5, Oakridge Units 1-4, Twin Bridges Units 1-8, Vermillion Units 1-8, & Wabash River Unit 8 were implemented per Docket ER16-435. Cinergy JTS TPZ rates decreased by 2.05%.
- In Hoosier Energy oTPZ, interim rates were implemented for WVPA Lawrenceburg Units 5 & 6 per docket ER16-435. Hoosier Energy TPZ rates decreased by 2.26%.
- Corrected the load values in the Entergy Mississippi zone. Entergy Mississippi is reporting SMEPA's load. Entergy Mississippi TPZ rate decreased by 0.21%.
- MISO average schedule 2 rates decreased by 0.32%.
- Schedules 7, 8 & 9
- Reduced the ROE per docket EL 14-12 for all TOs.
- Incorporated the RTO adder as applicable.
- Corrected the load values in the Entergy Mississippi zone. Entergy Mississippi is reporting SMEPA's load.
- Overall MISO Rate Change: (5.76%).
- Schedule 26
- Reduced the ROE per docket EL 14-12 for all TOs.
- Incorporated the RTO adder as applicable.
- Corrected the load values in the Entergy Mississippi zone. Entergy Mississippi is reporting SMEPA's load.
- Overall MISO Rate Change: (6.74%).
- Schedule 26-A
- Reduced the ROE per docket EL 14-12 for all TOs.
- Incorporated the RTO adder as applicable.
- Schedule 33
- Corrected the load values in the Entergy Mississippi zone. Entergy Mississippi is reporting SMEPA's load.
- Overall MISO Rate Change: (6.74%).
- Schedule 42-A
- Incorporated revisions related to changes to the ROE.
- Corrected the load values in the Entergy Mississippi zone. Entergy Mississippi is reporting SMEPA's load.
- EATO Rate Change: (0.05%), EMTO Rate Change: (0.24%), ETTO Rate Change: (0.08%).
- Schedule 42-B
- Incorporated revisions related to changes to the ROE.
- Corrected the load values in the Entergy Mississippi zone. Entergy Mississippi is reporting SMEPA's load.
- EATO Rate Change: (0.08%), ELTO Rate Change: (0.91%), EMTO Rate Change: (1.03%), ETTO Rate Change: (0.83%).
- Schedule 45
- Incorporated revisions related to changes to the ROE.
- Corrected the load values in the Entergy Mississippi zone. Entergy Mississippi is reporting SMEPA's load.
- MISO Overall Rate Change: (8.39%).
These changes are effective October 1, 2016.
September 21, 2016:
Rate changes were processed to incorporate the following:
- Added a new pricing zone for Entergy New Orleans per docket ER16-967.
- Removed Entergy New Orleans load and revenue requirement from the Entergy Louisiana zonal rate calculations.
- This resulted in changes to rates in the ELTO TPZ for schedules 1, 2, 7, 8, 9, 41 and 42-B.
- Schedule 2
- Added Entergy New Orleans (ENTO) as a new Transmission Pricing Zone (TPZ) per Docket ER16-967. ELTO rates increased by 8.8%.
- In ITCM Zone, added LWP Lessee LLC pursuant to order ER16-1923. ITCM rates increased by 41.9%.
- MISO average schedule 2 rates increased by 1%.
- Schedule 36
- Discontinued billing to NYISO and PJM for the Bunce Creek PARs cost recovery from International Transmission Company (ITC) per docket ER11-1844.
- The revenue requirements have been set to zero.
These changes are effective September 1, 2016.
August 17, 2016:
Rate changes were processed to incorporate the following:
- Schedule 2
- In EATO TPZ, interim rates for Independence 1 & 2 and White Bluff 1 & 2 for City of West memphis (EL16-17) and Conway (EL 16-18) were implemented effective 8/1/2016. EATO TPZ decreased by 0.355%
- Memphis (EL16-17) and Conway (EL16-18) were implemented effective 8/1/2016. EATO TPZ decreased by 0.355%.
- In the Ameren IL TPZ, changed the name of AmerGen CPS to Exelon Generation Company, LLC.
- MISO Schedule 2 average rate decreased by 0.4118%.
- Schedule 47
- Entergy Mississippi notified MISO that the Transition Cost Balance was fully recovered by 7/31/16. MISO will zero out the Sch. 47 rate for the EMTO TPZ effective 8/1/16.
These changes are effective August 1, 2016.
July 21, 2016:
Rate changes were processed to incorporate the following:
- Schedule 2
- In Michigan Joint Zone TPZ, Wolverine's Alpine Units 1 & 2 (ER16-1036) added to active units as of 7/1/16. METC TPZ increased by 5.48%.
- In Cinergy TPZ, the revenue requirement for IMPA Gibson Unit 5 (EL16-14) was reduced from $67,565 to $63,000. Cinergy TPZ reduced by 0.05%.
- MISO system-wide rates increased by 0.42% for July.
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:
- Schedule 1
- The divisor for SMMPA and MISO was updated to reflect the Interim Implementation of the RPU/SMMPA Settlement Agreement in ER14-2154/ER15-277.
- MISO system-wide rates decreased 0.01%
- Schedules 2
- In the Duke-Indiana zone, the revenue requirement associated with WVPA’s share of Gibson #5 was incorporated per Docket ER16-1266 and Wabash River #1 was retired.
- In the METC zone, the New Covert unit moved to PJM per Docket ER16-1226, and the Endicott unit was retired per Docket EL16-52.
- In the ATC zone, the revenue requirement associated with Calpine-Rockgen #1 was incorporated per Docket ER16-1266.
- In the Entergy Arkansas zone, the revenue requirement associated with Empire District’s share of Plum Point was incorporated per Docket ER16-1266, MJMEUC’s share of Plum Point was incorporated per Docket EL16-26, the Conway portion of Independence #1 & #2 and White Bluff #1 & #2 was incorporated per Docket EL16-18, the West Memphis portion of Independence #1 & #2 and White Bluff #1 & #2 was incorporated per Docket EL16-17, and Mabelvale Units #1 & #3 were retired.
- In the Entergy Louisiana zone the Michoud #2, Willow Glenn #2 & #4, and Ninemile #3 units were retired.
- In the Ameren Illinois zone, the revenue requirement associated with the Tilton facility was incorporated per Docket ER16-1266, and the Wood River Units #3 & #4 were retired per Docket ER16-1445.
- In the Entergy Texas zone the Sabine #2 unit was retired.
- MISO system-wide rates decreased 0.73%.
- Schedules 7, 8, & 9
- WPPI Energy was added as a new Transmission Owner per Docket ER16-1333.
- MISO system-wide rates increased 5.65%.
- Schedules 26 & 37 & 38
- WPPI Energy was added as a new Transmission Owner per Docket ER16-1333.
- MISO system-wide rates increased 3.07%.
These changes are effective June 1, 2016.
May 18, 2016:
Rate changes were processed to incorporate the following:
- Schedule 1
- The divisor for SMMPA and MISO was updated to reflect the Interim Implementation of the RPU/SMMPA Settlement Agreement in ER14-2154/ER15-277.
- MISO system-wide rates decreased 0.01%
- Schedules 2
- In the Duke-Indiana zone, Interim Implementation of the Settlement Agreemetn in Docket ER16-200 was incorporated.
- In the METC zone, three units were added for Wolverine (ER16-1036). Revised revenue requirements were implemented for Consumers (ER16-1058).
- In the MidAmerican zone, a revised Stated Rate was implemented (ER16-1062).
- The divisor for SMMPA and MISO was updated to reflect the Interim Implementation of the RPU/SMMPA Settlement Agreement in ER14-2154/ER15-277.
- MISO system-wide rates decreased 7.82%.
- Schedules 7, 8, & 9
- Interim implementation of the RPU / SMMPA Settlement Agreement in ER14-2154/ER15-277 was incorporated.
- MISO sytsem-wide rates decreased 0.02%.
- Schedules 26 & 37 & 38
- Interim implementation of the RPU / SMMPA Settlement Agreement in ER14-2154/ER15-277 was incorporated.
- MISO system-wide rates increased 0.06%
- Schedules 33
- The divisor for SMMPA and MISO was updated to reflect the Interim Implementation of the RPU/SMMPA Settlement Agreement in ER14-2154/ER15-277.
- MISO system-wide rates increased 0.01%
- Schedules 45
- The divisor for SMMPA and MISO was updated to reflect the Interim Implementation of the RPU/SMMPA Settlement Agreement in ER14-2154/ER15-277.
- MISO system-wide rates increased 0.03%
- Schedules 47
- Full recovery occurred in the Entergy Louisiana and Entergy Texas pricing zones as of the end of April, 2016. Per the Sch. 47 Tariff requirements, the rate was turned off.
- There are no MISO system-wide rates for this Schedule.
These changes are effective May 1, 2016.
April 27, 2016:
Rate changes were processed to incorporate the following:
- Schedule 2
- In the Entergy Louisiana (ELL) zone, Michoud #3’s revenue requirement was removed due to a retirement.
- In the BREC zone, Reid #1’s revenue requirement was removed due to a suspension.
- In the Entergy Arkansas zone, Empire District - Plum Point facility’s revenue requirement was removed since their qualified generator status changed.
- In the ATC-WPL zone, Calpine-RockGen #1’s revenue requirement was removed since their qualified generator status changed.
- In the DEI and HE zones, WVPA revenue requirement for 24 units was added per the order in Docket ER16-435.
- In the METC, AMIL, and ITC zones, NERC ID transfers were processed for the Jackson, Shelby, and East China, respectively. There was no impact to the Sch. 2 rates for these transfers.
- MISO system-wide rates decreased 0.14%.
- Schedules 7, 8, & 9
- Consumers Energy was integrated into rates as a new Transmission Owner in the Michigan Joint Zone (METC) pricing zone per Order in Docket ER16-844.
- Interim implementation of the Entergy-only Regional Through and Out Rate (RTOR) for qualifying customers per the Settlement Agreement in Docket ER14-19.
- MISO system-wide rates increased 0.24%.
- Schedules 26, 37, & 38
- Interim implementation of the Entergy-only Regional Through and Out Rate (RTOR) for qualifying customers per the Settlement Agreement in Docket ER14-19.
- Modification of the billed entity for Schedule 37 (ATSI instead of PJM) per Docket ER11-2814.
- No change to the MISO system-wide rates from these items.
These changes are effective April 1, 2016.
March 16, 2016:
Rate changes were processed to incorporate the following:
- Schedule 2
- In the Entergy Louisiana (ELL) zone, the Occidental – Taft facility’s revenue requirement was reduced per the terms of the Settlement Agreement in Docket ER15-878).
- In the Ameren Illinois zone, the Tilton facility’s revenue requirement was zeroed out since they pseudo-tied out of MISO.
- In the Entergy Arkansas (EAI) zone, the Union Power Partners facility terminated its Sch. 2 revenue requirement in Docket ER16-1146.
- MISO system-wide rates decreased 2.85%
- Schedules 7, 8, & 9
- CWLP and SMMPA had errors corrected related to their 6/1/15 Attachment O submission. These changes affected rates in the ITCM, CWLP, GRE, NSP, and SMMPA zones.
- MISO system-wide rates increased 0.01%
- Schedules 26, 37, &38
- CWLP and SMMPA had errors corrected related to their 6/1/15 Attachment GG submission. These changes affected rates in most zones due to MTEP Project allocations.
- MISO system-wide rates decreased 0.08%.
These changes are effective March 1, 2016.
February 20, 2016:
Rate changes were processed to incorporate the following:
- Schedule 2
- In the Entergy Arkansas (EAI) zone, Entergy Power, LLC became a qualified generator effective 2/1/16. Its revenue requirement was approved in Docket ER14-2502.
- Schedules 7, 8, & 9
- SMEPA had changes to its Attachment O template approved in Docket ER15-1345. These changes affected rates in the SMEPA and Entergy Mississippi zones.
- Schedules 47
- Entergy Arkansas notified MISO that the Transition Cost Balance was fully recovered by 1/31/16. As a result, the rate for the Entergy Arkansas (EAI) zone was taken to zero effective 2/1/16.
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:
- Rate changes were processed to incorporate the January updates of Attachments O/GG/MM/SS/ZZ for Transmission Owner’s using a forward-looking Attachment O. Other changes reflected in the update include the following:
- Schedule 2
- In the Ameren Illinois (AIC) Zone, removed Dynegy-Edwards #1’s revenue requirement pursuant to ER16-233.
- In the Duke-Indiana (CIN) Zone, Duke-Indiana was approved for generator-specific revenue requirements for 48 units pursuant to ER16-200. Also, IMPA had a revenue requirement approved for its share of Gibson Unit #5 pursuant to EL16-14.
- In the NISPCO Zone, NIPSCO was approved for generator-specific revenue requirements for 12 units pursuant to ER15-2426.
- Schedules 7, 8, & 9
- Willmar Municipal Utilities (WMU) has been included as a Forward-looking TO for the first time in the GRE Pricing Zone (ER16-18). They were previously a 30.9 Customer of GRE.
- Prairie Power (PPI) has been included as a Forward-looking TO for the first time in the AIC Pricing Zone (ER15-2364). They were previously a Historical TO in the AIC Pricing Zone.
- MP had Transmission Rate Incentives approved for its GNTL Project effective 1/1/16 (ER16-118).
- Schedule 26—Four new MTEP15 projects were added.
- Manitoba Hydro (MHEB) provided revised rates for Schedules 1, 2, 7, 7A, 8, and 11. They also eliminated the NITS rate previously posted by MISO.
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:
- On August 31, 2015, in Docket No. ER13-948-007, et al., the Federal Energy Regulatory Commission granted the Entergy Operating Companies a temporary and limited waiver of their transmission formula rate implementation protocols and permission to maintain their currently-effective transmission revenue requirements in effect through October 31, 2015. Rate changes have been processed to reflect the November 1, 2015 rate update for the Entergy Operating Companies as follows:
- Entergy Arkansas Pricing Zone (EATO) - Entergy Arkansas, Inc. (EAI)
- Entergy Louisiana Pricing Zone (ELTO) - Entergy Louisiana, LLC (ELL), Entergy New Orleans, Inc. (ENO), Entergy Gulf States Louisiana, LLC (EGSL)
- Entergy Mississippi Pricing Zone (EMTO) - Entergy Mississippi Inc. (EMI)
- Entergy Texas Pricing Zone (ETTO) - Entergy Texas, Inc. (ETI)
- Ameren Missouri Pricing Zone (AMMO) - Load reduction for the Southeast Missouri (Bootheel) Load
- Schedule 33 – In the ATC Pricing Zones (MGE, WPS, ALTE, WEC, UPPC), added revenue requirement for additional Blackstart-capable units for Wisconsin Electric Power Company (WEPM) pursuant to ER13-2019. This caused a 3.40% increase in MISO’s through and out rate.
- Schedule 2 - Implemented the AECC Settlement approved in Docket ER15-953. Revenue requirement for 10 generators decreased, effective retroactive to 4/1/15. This caused a 0.11% decrease in MISO’s through and out rate.
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:
- Schedule 2 rate changes were made in the Entergy Louisiana Pricing Zone for the following:
- Removal of the revenue requirement for the retired Little Gypsy #1 generator and associated Little Gypsy Common facilities.
- The NERC ID was changed from EGMP to ELMP for 12 generators due to the EGSL to ELL merger.
This resulted in the following Sch. 2 rate impacts:
- Entergy Louisiana Pricing Zone Sch. 2 rate decreased 0.902%.
- The MISO average Sch. 2 rate decreased 0.113%.
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:
- Schedule 2 rate changes were made for the following:
- Entergy Arkansas Zone – reduced the revenue requirement for EDE – Plum Point from $84,092 to $76,000 per FERC approved settlement agreement in Docket ER15-1405.
- Michigan Joint Zone – reinstated the $881,000 revenue requirement for the Renaissance facility, which was acquired by DTE Electric (DEMO) per FERC Docket EC15-158.
This resulted in the following Sch. 2 rate impacts:
- Entergy Arkansas Sch. 2 rate decreased 0.0546%.
- Michigan Joint Zone Sch. 2 rate increased 2.9525%.
- The MISO average Sch. 2 rate increased 0.4091%.
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:
- Schedule 2 rate changes were made for the following:
- Entergy Arkansas Zone - added Plum Point- MEAM ownership portion per FERC Docket NJ15-13.
- Entergy Arkansas Zone – added City Water and Light Plant of the City of Jonesboro’s ownership portion of the following generators, per FERC Docket EL15-51
- Independence Unit 1
- Independence Unit 2
- Independence Common
- White Bluff Unit 1
- White Bluff Unit 2
- White Bluff Common
This resulted in the following Sch. 2 rate impacts:
- Entergy Arkansas Sch. 2 rate increased 2.0751%.
- The MISO average Sch. 2 rate increased 0.1414%.
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:
- Schedule 2 rate changes were made for the following:
- Entergy Arkansas Zone - added ETEC - Plum Point ownership portion per FERC Docket EL15-54.
- Entergy Louisiana Zone – added Alexandria – Bayou Cove per FERC Docket EL15-49 and Big Cajun I per FERC Docket ER15-1136.
- The Big Rivers divisor was also corrected for an error in the June, 2015 Attachment O submission.
This resulted in the following Sch. 2 rate impacts:
- Entergy Arkansas Sch. 2 rate increased 0.59%.
- Entergy Louisiana Sch. 2 rate increased 2.87%.
- Big Rivers Sch. 2 rate decreased (2.19%).
- The MISO average Sch. 2 rate increased 0.36%.
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:
- ALP Utilities (Alexandria, MN) has been added as a historical TO in the OTP pricing zone (ER15-1394).
- Schedule 2 rate changes were made for the following:
- Entergy Arkansas Zone - added Empire District - Plum Point ownership portion per FERC Docket ER15-1405.
- ATC-WPS Zone - added Marshfield per FERC Docket ER15-900
- Changed the NERC ID for from TEA to KMPA for KMPA’s portion of the Prairie State Energy Center in the Ameren IL Zone.
- The divisors were also updated for the June Rate Update.
- This resulted in the following Sch. 2 rate impacts:
- Entergy Arkansas Sch. 2 rate increased 4.10% (0.61% of that was due to the EDE-Plum Point add, and the divisor change accounted for the rest).
- ATC-WPS Sch. 2 rate increased 0.86%.
- The MISO average Sch. 2 rate decreased (0.04%).
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:
- Entergy Arkansas Sch. 2 rate decreased 0.553%
- The MISO average Sch. 2 rate decreased 0.0378%.
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:
- Schedule 2 — In the Entergy Arkansas Zone, added 8 AECC generators, pursuant to ER15-953.
- Schedule 2 — In the Entergy Louisiana Zone, added Taft Cogeneration (OPSI - ER15-878) and Bayou Cove (NRG - ER15-502 ) generators.
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:
- Schedule 2 — Tariff Pricing reduced the revenue requirement for 57 generators in the Entergy Arkansas Zone, Entergy Louisiana Zone, Entergy Mississippi Zone, and Entergy Texas Zone. These reductions were ordered as a result of settlement proceedings in FERC Docket ER14-108.
- Schedule 2— Removed the revenue requirement for a retired generator in the Ameren Missouri Zone.
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:
- Schedule 2 — Added Plum Point Energy Associates (PPEA) to the Entergy Arkansas Pricing Zone pursuant to FERC Docket ER14-2046.
- Schedule 2—In the Entergy Arkansas Zone, revised Independence Unit 2 – ISES (ETEC)’s revenue requirement pursuant to FERC Docket ER14-1458.
- Schedule 2—In the Entergy Louisiana Zone, revised the revenue requirement for Nelson 6 (ETEC) pursuant to FERC Docket ER14-1458.
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:
- Schedule 1 — Added true-up adjustments as a result of ER12-2129.
- Schedule 2—In the Entergy Arkansas Zone, revised Union Power Partner’s revenue requirement pursuant to ER15-81.
- Schedule 2—In the Michigan Joint Zone, removed the revenue requirement for Renaissance Power.
- Schedule 26—Five new MTEP14 projects were added.
- Schedule 26—MTEP08 – Project #1024 costs were re-allocated to reflect Rochester Public Utilities (RPU) inclusion in this project.
- Schedule 33—In the ATC zones, added WEPCO units pursuant to ER13-2019.
- Marshall Municipal Utilities (MMU) has been included as a forward-looking TO (NSP pricing zone) for the first time (ER15-142)
- Rochester Public Utilities (RPU) has been included as a forward-looking TO (SMMPA pricing zone) for the first time (ER15-277)
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:
- Added the City of Alexandria (AXLT) to the CLECO pricing zone; the revenue requirement only (load was already being reported by CLECO) was added to the zone, effective 12/1/2014. (ER15-466)
- Added Rochester Public Utilities (RPU) to the SMMPA pricing zone; the revenue requirement and load were added to the zone, effective 12/1/2014. (ER14-2154)
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:
- Schedule 2
- Added the FERC approved revenue requirement for Pine Bluff Energy Center to the Entergy Arkansas Pricing Zone (ER14-2762).
- Added the FERC approved revenue requirement for Cottonwood to the Entergy Texas Zone (ER14-1619).
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:
- Schedule 7/8/9
- Added Glencoe, MN as a new Transmission Owner in the NSP pricing zone; their revenue requirement was added to the zone, effective 9/1/2014. No new load added since Glencoe's load was already being reported by NSP.
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:
- Schedule 2 rate changes were processed to incorporate the FERC-approved revenue requirement for LAGN/NRG’s Big Cajun II Generation Facility (Units 1, 2, & 3) to the Entergy Louisiana Transmission Pricing Zone (ER14-2080).
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:
- Added the City of Ames (AMES) to the MEC pricing zone; the revenue requirement and load were added to the zone, effective 6/1/2014.
- Added Arkansas Electric Cooperative (AECC) to the Entergy Arkansas (EATO) pricing zone; the revenue requirement and load were added to the zone, effective 6/1/2014. (ER14-684)
- Schedule 2
- Added revenue requirement for Nelson 6 to the Entergy Louisiana Zone. (ER14-1458) Added revenue requirement for Independence - Unit 2 (ISES) to the Entergy Arkansas Zone. (ER14-1458)
- Schedule 47: Entergy Operating Companies MISO Transition Cost Recovery was created per FERC’s order in ER14-1645-000, et al.
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:
- Added the City of Ames (AMES) to the MEC pricing zone; the revenue requirement and load were added to the zone, effective 6/1/2014.
- Added Arkansas Electric Cooperative (AECC) to the Entergy Arkansas (EATO) pricing zone; the revenue requirement and load were added to the zone, effective 6/1/2014. (ER14-684)
- Added Marshall Municipal Utilities (Marshall) to the NSP pricing zone; the revenue requirement and load were added to the zone, effective 6/1/2014.
- Schedule 2
- Added revenue requirement for Nelson 6 to the Entergy Louisiana Zone. (ER14-1458) Added revenue requirement for Independence - Unit 2 (ISES) to the Entergy Arkansas Zone. (ER14-1458)
- Schedule 47: Entergy Operating Companies MISO Transition Cost Recovery was created per FERC’s order in ER14-1645-000, et al.
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:
- Schedule 2
- In the BREC Zone, revenue requirements for Coleman Units 1, 2, and 3 were removed pursuant to ER14-1391 and ER14-1392. This resulted in an 18.37% decrease in the BREC Zone, and a 0.19% decrease in the MISO through and out rate.
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:
- Schedule 33
- Io In the DPC Zone, added revenue requirement for Dairyland Power pursuant to ER13-1235, effective April 1, 2014. This caused a 9.3% increase in MISO's through and out rate.
- Schedule 26/ Schedule 38
- An adjustment was made to correct an allocation error for ATC’s MTEP project 2846. There is no impact on MISO’s through and out rate. There are allocation shifts in the following zones: CIN, NIPS, METC, ITC, ITCM, AMMO, AMIL, ATC, NSP, MP, GRE, OTP, MEC, DPC. This correction requires billing adjustments from January 2012 to March 2014. These adjustments will be processed in the future.
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:
- Schedule 2
- In the Ameren Illinois Zone, the NERC ID for Dynegy Power Marketing was changed.
- In the Ameren Illinois Zone, AmerenEnergy Medina Valley CoGen transferred Gibson City and Grand Tower assets to Teneska.
- In the Michigan Joint Zone, Bear Energy's NERC ID was changed to reflect the transfer of assets from AlphaGen to Teneska.
- These changes were NERC ID’s only, and did not affect rates.
- Schedule 7/8/9
- An adjustment was made for PPI (AMIL zone) to reflect PPI's Interim Attachment O, due to the outcome of the Settlement in EL13-83. This resulted in a 0.02% decrease in MISO's through and out rate for point to point service under Schedules 7 and 8.
- A rate update was processed to calculate transmission rates for Central Iowa Power Cooperative (CIPCO), as a result of the CIPCO Coordination Agreement (ER12-971/ER13-896).
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:
- Schedule 7/8/9 – NSP submitted a corrected Attachment O. This caused a minor shift in zonal revenue requirement allocation, with a slight increase in the GRE Zone, and an equal decrease in the NSP Zone. There was no impact to the MISO system rate.
- Schedule 2 – Viaduct generator was removed from the Ameren Missouri (AMMO) pricing zone.
- Schedule 33 – The NERC ID for Interstate Power & Light was changed from ALTM to ALTW. This update corrects the recipient of Schedule 33 revenues for this unit from ALTM to ALTW. As an ID-only change, this update has no impact on the MISO system rate for Schedule 33.
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:
- Central Minnesota Municipal Power Agency (CMMPA) was approved to begin utilizing a forward-looking test period (ER13-2468).
- Dairyland Power Corporation (DPC) was approved to begin utilizing a forward-looking test period (ER14-102/ER14-102-001).
- Schedule 2 – Added new generators’ Revenue Requirements to Entergy Pricing Zones (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas (ER14-108), and added Revenue Requirement for Union Power Partners to the Entergy Arkansas Pricing Zone (ER14-296)
- Schedule 33 – Added Revenue Requirement for Interstate Power & Light to the ITCM Pricing Zone. (ER13-2036).
- Schedule 45/Attachment ZZ – processed the initial rate calculation for implementation of this new schedule - Cost Recovery of NERC Recommendation or Essential Action (ER13-841), utilized by Minnesota Power (MP).
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:
- Central Minnesota Municipal Power Agency (CMMPA) was approved to begin utilizing a forward-looking test period (ER13-2468).
- Dairyland Power Corporation (DPC) was approved to begin utilizing a forward-looking test period (ER14-102/ER14-102-001).
- Schedule 2 – Added new generators’ Revenue Requirements to Entergy Pricing Zones (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas (ER14-108), and added Revenue Requirement for Union Power Partners to the Entergy Arkansas Pricing Zone (ER14-296)
- Schedule 33 – Added Revenue Requirement for Interstate Power & Light to the ITCM Pricing Zone. (ER13-2036).
- Schedule 45/Attachment ZZ – processed the initial rate calculation for implementation of this new schedule - Cost Recovery of NERC Recommendation or Essential Action (ER13-841), utilized by Minnesota Power (MP).
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:
- Entergy Arkansas Pricing Zone (EATO) - Includes Entergy Arkansas, Inc. (EAI) – (ER14-107).
- Entergy Louisiana Pricing Zone (ELTO) - Includes Entergy New Orleans, Inc. (ENO), Entergy Gulf States Louisiana, LLC (EGSL), Entergy Louisiana, LLC (ELL), and Cleco Power LLC - (ER14-107)
- Entergy Mississippi Pricing Zone (EMTO) - Includes Entergy Mississippi Inc. (EMI) and South Mississippi Electric Power Association (SMEPA) - (ER14-107)
- Entergy Texas Pricing Zone (ETTO) - Includes Entergy Texas, Inc. (ETI), East Texas Electric Cooperative Inc. (ETEC). This includes Attachment O’s for Sam Houston Electric Co-op, Tex-La Electric Co-op of Texas, Jasper-Newton Electric Co-op, Deep East Texas Electric Co-op - (ER14-107/ER13-1827):
- CLECO Power Pricing Zone (CLECO) - Includes Cleco Power LLC - (ER13-1547)
- South Mississippi Electric Power Association Pricing Zone (SME) - Includes SMEPA - (ER14-107)
- Lafayette City-Parish Consolidated Government Pricing Zone (LAFA) - Includes LAFA - (ER14-107)
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:
- Minnesota Municipal Power Agency (MMPA) was added as a Transmission Owner in the Northern States Power (NSP) Pricing Zone, effective 06/01/13.
- Prairie Power, Inc. (PPI) was added as a Transmission Owner in the Ameren Illinois (AMIL) Pricing Zone, effective 06/01/13.
- Schedule 2 - Added new generator’s Revenue Requirement to Michigan Joint Zone (Wolverine – Gaylord facility), effective 06/01/13 (ER13-1215).
- Schedule 2 - Processed a NERC ID change (Calpine Fox) from WPSM to WPS (no impacts to Sch 2 rates from this transaction).
- Schedule 2 - Removed Calpine Riverside's Revenue Requirement upon its 05/31/13 expiration, pursuant to settlement proceedings in ER09-1313.
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:
- Benson Municipal Utilities has been added to the OTP pricing zone.
- Detroit Lakes Public Utilities has been added to the OTP pricing zone.
- AIC was approved to begin utilizing a forward-looking test period effective 01/01/13 (ER12-2216).
- NIPSCO was approved to begin utilizing a forward-looking test period effective 01/01/13 (ER13-150).
- MDU was approved to begin utilizing a forward-looking test period effective 01/01/13 (ER13-307).
- Schedule 2 - Removed the revenue requirements for the Hutsonville and Meredosia plants in the Ameren IL zone. These plants are no longer capable of providing reactive power following the MISO approved suspension of operations. Effective 01/01/13, compensation under Sch 2 is no longer claimed for these plants.
- Pella regulatory expense correction.
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:
- Kentucky Municipal Power Agency (KMPA), Docket # EL12-94
- Illinois Municipal Electric Agency (IMEA), Docket # EL12-93
- Missouri Joint Municipal Electric Utility Commission (MJMEUC), Docket # EL12-95
- American Municipal Power, Inc. (AMP), Docket # EL12-91
- Prairie Power, Inc. (SOY), Docket # EL12-90
- Indiana Municipal Power Agency (IMPA), Docket # EL12-97
- Southern Illinois Power Cooperative (SIPC), Docket # EL12-92
- Northern Illinois Municipal Power Agency (NIMPA), Docket # EL12-96
- Lively Grove Energy Partners (LGEP), Docket # ER12-2353
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:
- Kentucky Municipal Power Agency (KMPA), Docket # EL12-94
- Illinois Municipal Electric Agency (IMEA), Docket # EL12-93
- Missouri Joint Municipal Electric Utility Commission (MJMEUC), Docket # EL12-95
- American Municipal Power, Inc. (AMP), Docket # EL12-91
- Prairie Power, Inc. (SOY), Docket # EL12-90
- Indiana Municipal Power Agency (IMPA), Docket # EL12-97
- Southern Illinois Power Cooperative (SIPC), Docket # EL12-92
- Northern Illinois Municipal Power Agency (NIMPA), Docket # EL12-96
- Lively Grove Energy Partners (LGEP), 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 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:
- On June 16, 2009, as amended September 18, 2009, Riverside Energy Center, LLC (“Riverside”) and RockGen Energy, LLC (“RockGen”) submitted a revised Rate Schedule FERC No. 2 between Riverside and American Transmission Company LLC (“American Transmission”) as well as a revised Rate Schedule FERC No. 3 between RockGen and American Transmission. These filings provided for Riverside Energy’s and RockGen’s cost-based revenue requirements in the amounts of $1,100,000 and $700,000 respectively for Reactive Supply and Voltage Control Services. The Federal Energy Regulatory Commission (“Commission”) conditionally accepted the submittals for filing, effective June 1, 2009 as requested.
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:
- Schedule 1 was revised to reflect the following change:
- An error was discovered in the July 2009 rates related to the revenue requirement of ITC and METC that were effective June 1, 2009. The Schedule 1 reflects the correction.
- Schedule 2 change:
- Ameren units [1]: The July 30, 2009 FERC Order in docket No. ER09-398 approved, subject to refund, a revenue requirement of $5.4 million effective 8/1/09. The previous revenue requirement was $7,584,891.
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:
- Schedule 2 changes:
- Calpine Riverside and Calpine RockGen Energy: An agreement by Riverside Energy Center, LLC, Docket No. ER04-1055 and RockGen Energy, LLC, Docket No ER04-1059 was approved by FERC issued on June 20, 2005 where RockGen and Riverside had a stated revenue requirement effective through May 31, 2009. As of June 16, 2009 Riverside and RockGen Energy filed (ER09-1312 & ER09-1313) which was a request for a revised revenue requirement to become effective as of June 2009. As of the date of this memo FERC has not ruled on the revised revenue requirements. Therefore, both parties revenue requirements will be set to “0” (zero) for the billing month of July, effective June 1, 2009, pending the outcome of their recent filings.
- Dynegy: Updated Rates due to Dynegy Order EL05-72-006 whereas the revenue requirement was revised from $3,798,367 in June 2009 to $3,980,731 and is effective July 1, 2009.
- Duke: Updated Rates due to Duke Order ER07-1383, effective November 1, 2008. Changed stated rate from .216/KW month to .1184/KW month.
- Cannon Falls: Updated NERC ID from INVE to INVM – See attachment, effective July 1, 2009.
- Schedules 1, 2, 7, 8, 9, and 26:
- ITC Midwest: ITCM discovered an error in their divisor; ITCM is correcting the divisor for the ITCM pricing zone to 2,951 MW and is effective from June 1, 2009.
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:
- Sinks associated with undiscounted interfaces (IMO, SPP, and SERC) – the rates will be the same as Schedule 7 or 8.
- Sinks associated with discounted interfaces (MAPP and MISO) - the Schedule 14 portion of the discounted rate has been removed. These rates have been revised from the February 1, 2008 posting.
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.
- ATSI changed its Schedule 2 rates effective June 1.
- ITC-DTE changed its Schedules 2, 3, 5 & 6 effective June 1.
- ATSI now has a Commission order accepting the voltage differentiated rates.
- Ameren-UE/CIPS changed its Attachment O and the rate changed.
- The Commission ordered a reduction in Return On Equity (ROE) as used in Attachment O. The result is to drop the price for Schedules 7, 8 & 9 in many pricing zones.
- Ameren-IP made an accounting change that increases the Attachment O rate.
- Midwest ISO System Wide Average rate also changed.
- Ancillary service rates are affected.
- The Pricing by Sink tab reflects these changes.
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 8 | Schedule 14 | Total |
| 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.