Partners in Business Meeting Meeting Kick-Off Mike Dabney Manager, - PowerPoint PPT Presentation

Why Transmission Matters CLICK TO EDIT MASTER TITLE STYLE • When an E-3 tornado drove through central Marshalltown July 19, the storm tore down 37 poles on the main 34.5kV line through town • Structures built when Lyndon Johnson was president • Recognizing the variability of wind and storms, noteworthy that just half a mile away, similar voltage line rebuilt in 2014 suffered no impacts 27

Agenda CLICK TO EDIT MASTER TITLE STYLE • The value of transmission: • Reliability • Resiliency • Accommodating generation changes • Congestion reduction • Market efficiency/ Economic impact • How you see it 28

Critical Issues – Changing Generation CLICK TO EDIT MASTER TITLE STYLE Hydroelectric Natural Gas 3% 1% Nuclear 10% Wind Coal 37% 44% Coal 86% Nuclear Natural Other 9% Gas 1990 2017 0% 8% Hydroelectric 2% Source: Energy Information Administration: Net Generation by State by Type of Producer by Energy Source 29

Critical Issues – Generation Retirements CLICK TO EDIT MASTER TITLE STYLE Lansing 2-3 50 MW Stoneman Nelson Dewey 1-2 40 MW 200 MW Neal 1-2 496 MW DBQ 1-3-4-5 129 MW Sutherland 2 38 MW Sutherland 1-3 ML Kapp 1 109 MW 19 MW Council Bluffs 1-2 6 th St. 2-4-7-8 131 MW 68 MW Riverside 3-5 141 MW Agency 1-2-3-4 70 MW 30

Critical Issues – Generation Additions CLICK TO EDIT MASTER TITLE STYLE Short-term/Already announced: • MidAmerican announced Wind XI, planned $3.6B investment, 2,000 MW of new wind projects • Alliant Energy announced planned $1B investment, up to 500 MW of new wind projects • Dozens of additional developers proposing hundreds of megawatts of new wind projects 31

Transmission Upgrades for MGS CLICK TO EDIT MASTER TITLE STYLE Major Upgrades • Line relocations at the Marshalltown sub • Rebuild the Newton-Prairie City 69kV line to current 69kV standards – 5.55 miles • Jasper-Aurora Heights – 4 miles • Blairstown-Marshalltown uprate – structure replacements 32

Multi-Value Projects CLICK TO EDIT MASTER TITLE STYLE Project 3: • Joint ITC/MidAmerican Energy Company (MEC) Project • ~145 miles in Iowa, ~70 in Minnesota Project 4: • Joint ITC/MEC Project • ~190 miles in Iowa Project 5: • Joint ITC/ATC/DPC Project • Preferred route ~102 miles in Iowa, Wisconsin • Status: Ongoing regulatory process; targeted in-service 2023 Project 7: • Joint ITC/MEC/Ameren Missouri Project • ~90 miles in Iowa, Missouri • Status: Under construction; targeted in-service 2019 33

Critical Issues – Accommodating Generation CLICK TO EDIT MASTER TITLE STYLE MVPs and other 345 kV lines built or under construction since 2010 support connection of renewables. “Wind farm development has followed as these lines have been approved and built. At the end of the day, that’s the point.” - Nathaniel Baer, Iowa Environmental Council, in Midwest Energy News 34

Why Transmission Matters CLICK TO EDIT MASTER TITLE STYLE • The Dubuque Power Plant powered Dubuque for more than 80 years, with plants at this site for more than 100 years • December 2014, Alliant announced plant conversion to natural gas, before closing it in 2016 • Closings planned for three other plants in Cassville, Wisconsin, and Clinton, Iowa • To address the issues, ITC: • built Dubuque 8 th Street-Salem 161 kV line, • constructed the Hickory Creek substation, • rebuilt the Hickory Creek-Lore line • moved ahead with plans for the Cardinal- Hickory Creek MVP 35

Agenda CLICK TO EDIT MASTER TITLE STYLE • The value of transmission: • Reliability • Resiliency • Accommodating generation changes • Congestion reduction • Market efficiency/ Economic impact • How you see it 36

Market Analysis & Congestion Evaluation ( MACE ) CLICK TO EDIT MASTER TITLE STYLE • Causes of unexpected congestion  Forced outages of transmission facilities  Facility derates ( NERC alert, field inspection, etc .)  Unexpected generation patterns ( higher or lower wind output, forced generation outages, etc. ) • Program to help ITC monitor & minimize congestion in our footprints  Improve transmission system utilization  Reduce financial impact of outages on customers • Provides a relative benchmark for unhedged congestion 37

Congestion Cost Trend CLICK TO EDIT MASTER TITLE STYLE $180,000,000 $160,000,000 $140,000,000 $120,000,000 $100,000,000 $80,000,000 $60,000,000 $40,000,000 $20,000,000 $0 2012 Cumulative Total 2013 Cumulative Total 2014 Cumulative Total 2015 Cumulative Total 2016 Cumulative Total 2017 Cumulative Total 38

Agenda CLICK TO EDIT MASTER TITLE STYLE • The value of transmission: • Reliability • Resiliency • Accommodating generation changes • Congestion reduction • Market efficiency/ Economic impact • How you see it 39

ITC’s Grid Investment | Singular Focus CLICK TO EDIT MASTER TITLE STYLE Singular Focus  System investment and drive value to customers  Frequent and proactive customer engagement Forward Looking  Respond to needs of today while planning for the future needs and policy goals Interconnections  Expand access to competitive energy markets  Actively and collaboratively engage customers 40

ITC Value | Market Efficiency CLICK TO EDIT MASTER TITLE STYLE Project Name ITC Case Non-ITC Case What ICF studied: Two system models were Hazleton - Salem 345 kV line with developed, an ITC case and non-ITC case. a 2nd Salem 345/161 kV 448 MVA Yes No The non-ITC case excluded project were only transformer. Quad Cities-Rock Creek-Salem 345 constructed due to ITC’s approach to Yes Yes kV line transmission investment Rock Creek 345/161 kV Yes Yes transformer Modeled the Adjusted Production Cost (APC) Heron Lake-Lakefield 161kV line Yes No of each scenario rebuild Arnold-Vinton-Dysart-Washburn Yes No 161kV Reconductor 41

ITC Value | Market Efficiency CLICK TO EDIT MASTER TITLE STYLE Customer benefit: ITC’s recently constructed transmission projects saved customers in the MISO region $714 million between 2010 and 2015 alone in reduced energy production costs due to decreased system congestion, according to the ICF study. • Savings to Midwest customers: $172 million 42

ITC Value | Aggregated Results CLICK TO EDIT MASTER TITLE STYLE All Systems ~$1.4 Billion: Benefits accruing to all customers in all regions where ITC operates, resulting from ITC philosophy on system investment ITC Midwest ~$610 Million: Benefits accruing directly to ITCMW customers from ITC investment philosophy Not Studied  Benefits accrued from ITC’s approach to planned outages congestion management  Benefits accrued from reduced outage on the EHV transmission system 43

ITC Value | Economic Multiplier CLICK TO EDIT MASTER TITLE STYLE • Investing in infrastructure has an economic multiplier effect • Materials purchased • Services purchased • Employment • Example impacts for ITC Midwest: • $953M investment through 2013 generated $1.4B multiplier • Property tax payments in excess of $30M • Wind generation impacts of more than $2B 44

Why Transmission Matters – Economic Impact CLICK TO EDIT MASTER TITLE STYLE • Jackson County, Minnesota, experienced its peak population in 1940. Today, the population is 41% below what it was then • Jackson County is one of the most active wind farm counties in Minnesota: 12 wind farms with combined nameplate capacity of 346 megawatts. • 2009: County received less than 5% of general fund revenues from wind tax • 2017: County received $1.9 million (16% of general fund revenues), • 2018: County is slated to receive $2.2 million (20% of budgeted general fund revenues) (Source: Moody’s: Wind Farms Bring Windfalls, May 2018) 45

How you see it CLICK TO EDIT MASTER TITLE STYLE • Value is in the eye of the beholder • We will continue working with stakeholders to define the value of these investments in tangible terms • Important to hear your perspective 46

CLICK TO EDIT MASTER TITLE STYLE Questions?

CLICK TO EDIT MASTER TITLE STYLE System Performance Dan Daavettila – Senior Engineer, Operational Planning

CLICK TO EDIT MASTER TITLE STYLE Reliability Definitions • Planned Outage: A non-automatic • Momentary Outage: An automatic outage with advance notice for planned outage with an outage duration of less activities that may be deferred than one minute • Forced Outage: A non-automatic • Sustained Outage: An automatic outage for the purpose of avoiding outage with an outage duration of a emergency that cannot be deferred minute or greater • Automatic Outage: An outage that • External Outage: An outage with a results from the automatic operation of a cause that is external to, and outside switching device, causing an element to the control of, the transmission system change from an In-Service State to a not In-Service State

CLICK TO EDIT MASTER TITLE STYLE Reliability Benchmarking  ITC benchmarks performance against a broad group of peers  ITC targets top quartile performance for outages per circuit per year  2017 benchmarking group: 100 kV and above • 85 companies • 18,408 circuits • 74% of US and Canadian circuit miles Below 100 kV • 41 companies • 6,398 total circuits

CLICK TO EDIT MASTER TITLE STYLE Performance ITCT, METC, and ITCM all achieved top quartile performance in 2017 Lower is better

CLICK TO EDIT MASTER TITLE STYLE Performance The ITCM 69 kV system achieved top quartile performance in 2017 Lower is better

CLICK TO EDIT MASTER TITLE STYLE How Does Benchmarking Drive Performance? Double circuit design standard review process • 161kV double circuit design flashover study shows an expected 2.79 lightning related outages per hundred miles per year using standard insulators Is this acceptable? • Benchmarking defines the target performance – 0.524 lightning outages per hundred miles per year Redesign for target performance • Upgrading to larger insulators results in a cost effective improvement in system performance

CLICK TO EDIT MASTER TITLE STYLE Historical Outage Performance

CLICK TO EDIT MASTER TITLE STYLE Outage Response Fault Study • The relay group reviews the event and provides details and location Investigation or line patrol • Above 100 kV: All outages are investigated and a root cause identified • Less than 100 kV: All sustained outages, repeated momentary outages, and poor performing circuit outages are investigated for a root cause Human Performance • Events with a human performance factor are reviewed through the Event Free Performance Program

CLICK TO EDIT MASTER TITLE STYLE Operational Excellence ITC Operations Committee Representatives Results • Asset Management • Operational Awareness Outage • Engineering • Identify Root Causes Response • Operations • Identify Outage Trends And • Planning • Focused Investment Review • Design • Process Improvement • Stakeholder Relations • Outage Reduction • Human Performance

CLICK TO EDIT MASTER TITLE STYLE Operational Excellence Operations Committee Analysis  Review of the previous month’s outages  Did we adequately investigate the outage cause?  Do we agree on the root causes?  Have we had issues on this line/area historically?  What is the specific design/construction of the circuit?  Did the equipment operate as designed?  Apply lessons learned  Is the underlying problem present elsewhere?  Develop a corrective action plan  Follow through  Review and follow up on outstanding corrective action plans

CLICK TO EDIT MASTER TITLE STYLE Reliability Focused Investment Maintenance  Poor performing circuits are prioritized for maintenance related activities Capital Investment  Circuit outage data feeds into Planning’s circuit rankings  Capital improvement projects are proposed for all worst-ranking circuits

CLICK TO EDIT MASTER TITLE STYLE ITCM 69 kV Sustained Outage Breakdown LIGHTNING Percentage of UNKNOWN SYSTEM-PROT VEGETATION 3% 4% 2% 3% total outages by HUMAN initiating cause 4% EQUIPMENT WEATHER 37% 2013-2017 5% (5 year avg.) OTHER 8% LINES 12% EXTERNAL 22%

Historical Comparison – Outage Cause CLICK TO EDIT MASTER TITLE STYLE

CLICK TO EDIT MASTER TITLE STYLE Benchmark Comparison by Outage Cause 69 kV Sustained Outages per Circuit - 5 Year Avg. 0.16 0.14 0.12 0.1 0.08 0.06 ITCM Q3 0.04 Q2 Q1 0.02 0

CLICK TO EDIT MASTER TITLE STYLE ITCM 100 kV+ Sustained Outage Breakdown SYSTEM-PROT Percentage of 2% VEGETATION LIGHTNING total outages by 2% 4% UNKNOWN initiating cause WEATHER 6% OTHER 31% 2013-2017 6% EQUIPMENT (5 year avg.) 8% HUMAN 10% LINES 17% EXTERNAL 14%

CLICK TO EDIT MASTER TITLE STYLE Historical Comparison by Outage Cause

CLICK TO EDIT MASTER TITLE STYLE Benchmark Comparison by Outage Cause 100 kV+ Sustained Outages per Circuit - 5 Year Avg. 0.08 0.07 0.06 0.05 0.04 0.03 ITCM Q3 0.02 Q2 Q1 0.01 0

CLICK TO EDIT MASTER TITLE STYLE Impact and Risk Management Determine high impact work  Work that places significant load or generation at risk  Outages that cause significant voltage problems Identify unintended outcomes  Switching risks including tripping or operating breakers  Adjacent equipment  Faults/operations of significant lines Managing risk  System reconfiguration or redispatch  Patrolling important lines, reviewing and addressing known issues  Awareness internally and externally Approval from operational planning and the control room

CLICK TO EDIT MASTER TITLE STYLE Questions?

CLICK TO EDIT MASTER TITLE STYLE ITC MIDWEST 2019 Projected Rate Presentation Zach Paquette – Manager, Rates 67

CLICK TO EDIT MASTER TITLE STYLE Agenda • Discuss the 2019 Projected Formula Rate posting • Walk through the timeline and calculation of the Projected 2019 Revenue Requirement • Discuss key drivers of the Projected Rates • Describe the next steps for Stakeholders

CLICK TO EDIT MASTER TITLE STYLE Contents of the 2019 Projected Rate Posting On August 31, 2018, Documents included in the postings: ITCMW posted the 2019 • Workable populated Att. O Rate projected rates package Template on the MISO and OASIS • Underlying work papers websites. • Attachments GG and MM with related True-Ups • Schedule 1 Expense Projected Rates • Accounting disclosures

CLICK TO EDIT MASTER TITLE STYLE Formula Rate Protocol Cycle Projected Rate year (Jan 1 – Dec 31) Rate Posting Informational* Prior year FERC Projected Rate for Timeline True-Up Filing Form 1 Next year (Jun 1) (Mar 15) (Apr 18) (Sep 1) April July April January October Protocols Open Review Informational Formal Informal Process Exchange Period Challenge Due Challenge Due (Jun 1 – Dec 1) (Jan 31) (Apr 15)

CLICK TO EDIT MASTER TITLE STYLE ITC MIDWEST 2019 Attachment O – Projected Formula Rate 71

CLICK TO EDIT MASTER TITLE STYLE Steps to Derive the Projected 2019 Net Revenue Requireme nt 2019 Projected Rate Base Weighted Average Cost of Capital Step 1 $ 2,723,218,884 8.62% Allowed Return Operating Expenses + Income Taxes Step 2 $ 234,871,627 $ 235,860,861 Gross Revenue Requirement Revenue Credits and Offsets Step 3 $ 470,732,488 $ 131,669,492 Projected 2019 Revenue Requirement 2017 True-Up (Over) Recovery Step 4 $ 339,062,996 $ (860,096) Projected 2019 Net Revenue Requirement Step 5 $ 338,202,900 *Totals may not reconcile due to rounding

ITC Midwest’s 2019 Network Rate is $9.596/kW-Mo. CLICK TO EDIT MASTER TITLE STYLE Key Drivers ($ millions) $332M Higher Plant in Service MVP Projects #4 & #7 projected to go in service in 2019 | 34.5kV to 69kV Conversion Phase 1 $13M Higher Taxes Higher Rate Base (Income Taxes) | Higher Plant in Service (Property related TOIT) $4M Higher Depreciation & Amortization Expense Higher Plant in Service $28M Higher Revenue Offsets Higher MM (MVPs #4 and #7) *Totals may not reconcile due to rounding

CLICK TO EDIT MASTER TITLE STYLE Disclosures • In March 2017, the Financial Accounting Standards Board issued guidance (Accounting Standards Update No. 2017-07, Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost) on the presentation of net periodic pension cost and net periodic postretirement benefit cost for U.S. GAAP reporting purposes. Among other changes that did not affect the stand-alone FERC accounting and reporting for ITC Midwest, the new guidance allows only the service cost component of net benefit cost to be eligible for capitalization; previously, the overall net benefit cost was eligible for capitalization. ITC Midwest adopted the guidance effective January 1, 2018. Upon adoption and as permitted by FERC Docket No. AI18-1-000, we elected to change our capitalization policy for FERC accounting and reporting purposes to align with the capitalization accounting changes required for U.S. GAAP as a result of this guidance. • The impacts in 2019 projected rates of this accounting change is estimated to be a $0.1 million increase in capital assets, a $0.1 million decrease in G&A expense, and $0.1 million overall decrease in 2019 projected net revenue requirement.

CLICK TO EDIT MASTER TITLE STYLE Questions? 75

CLICK TO EDIT MASTER TITLE STYLE ITC Midwest Appendix 76

ITC Midwest’s Projected Rate Increased by $ 0.483/kW-Mo. CLICK TO EDIT MASTER TITLE STYLE 2019 2018 Increase/ Description % Variance Projected Projected (Decrease) $3,628,665,870 $3,296,062,190 $331,603,680 Projected Gross Plant in Service 472,428,570 471,478,800 949,770 Accumulated Depreciation (476,614,228) (436,430,887) (40,183,341) Deferred Income Taxes 45,532,493 (1,936,681) 43,595,812 M&S/Prepayment/CWC $2,723,218,884 $2,433,684,996 $289,533,888 12% Rate Base $234,871,627 $208,621,262 $26,250,365 Return on Rate Base 13% $34,517,333 $32,932,996 $1,584,337 O&M Expenses 40,931,609 40,262,946 668,663 A&G Expenses 63,656,976 60,100,000 3,556,976 Depreciation Expense 77,216,673 69,304,256 7,912,417 Income Taxes 19,538,270 14,789,000 4,749,270 ADIT Deferral & Taxes Other Than Income Taxes Total Operating Expenses $235,860,861 $217,389,198 $18,471,663 8% $131,669,492 $103,940,768 $27,728,724 Credits/Offsets (Sch. 26, 26A, PTP, rents) (860,096) (1,635,309) 775,213 True-Up Adjustments 338,202,900 320,434,383 17,768,517 Projected Net Revenue Requirement* 2,937,034 2,930,212 6,822 Projected Network Load (based on 12 CP, kW) $9.596 $9.113 $0.483 Projected Rate ($/kW-Mo) 5% *Totals may not reconcile due to rounding

CLICK TO EDIT MASTER TITLE STYLE Overview of Planned Capital Additions • The development of the annual Rate Base begins with a forecast of planned capital additions. • The ITC Midwest Planned Capital Addition slides identify expected line, substation, and other construction projects as they are currently known. • The projects identified represent our best estimates for projects to be initiated and completed. • Note that many factors such as regulatory approvals, construction resources, availability of materials, weather and other unforeseen events, could alter projections and schedules.

CLICK TO EDIT MASTER TITLE STYLE Major Planned Transfers to Plant in Service Projected Amount for the 13 Months Project Name Ended December 31, 2019 MVP #4 - Winco to Hazleton 345 kV line $ 158,459,514 34.5 kV to 69 kV Conversion Phase 1 109,517,005 MVP #7 – Zachary - Ottumwa 345 kV 34,397,654 Cedar Rapids - North Liberty Area 18,082,310 Communication Addition Program 8,778,429 N. Burlington to N. Burlington Tap 7,666,096 OH-UG NRUC/Reliability 7,126,896 Fairbank-Oelwein 69 kV Rebuild 5,694,233 Saling (Corydon) 69 kV Breaker Substation Rebuild 4,953,006 Kneedler (Mt. Ayr) 69 kV Breaker Substation Rebuild 4,467,672 Substation NRUC/Reliability 2,434,995

Step 1: Calculation of ITC Midwest’s Rate Base CLICK TO EDIT MASTER TITLE STYLE Rate Base Items 2019 Projected Amount 2018 Projected Amount Increase/(Decrease) % Variance Gross Plant in Service $3,628,665,870 $3,296,062,190 $322,603,680 - Accumulated Depreciation 472,428,570 471,478,800 949,770 Net Plant in Service* $3,156,237,300 $2,824,583,390 $331,653,910 12% + Deferred Income Taxes $(476,614,228) $(436,430,887) $(40,183,341) + Materials & Supplies 30,646,250 33,756,000 (3,109,750) + Land Held for Future Use - - - + Prepayments 3,518,444 2,627,000 891,444 + Working Capital 9,431,118 9,149,493 281,625 = Total Rate Base* $2,723,218,884 $2,433,684,996 $289,553,888 12% *Totals may not reconcile due to rounding

CLICK TO EDIT MASTER TITLE STYLE Step 2 & 3: Calculation of Rate of Return & Allowed Return Cost of Capital Weight Cost 2019 Projected WACC 2018 Projected WACC Increase/(Decrease) Equity 60% 11.32% 6.79% 6.79% Debt 40% 4.58% 1.83% 1.78% Rate of Return* 8.62% 8.57% Allowed Return 2019 Projected Amount 2018 Projected Amount Increase/(Decrease) % Variance Rate Base $2,723,218,884 $2,433,684,996 x Return (above) 8.62% 8.57% = Allowed Return* $234,871,627 $208,621,262 $26,250,365 13% *Totals may not reconcile due to rounding

Step 4 & 5: Operating Expenses & Total Gross Revenue Requirement CLICK TO EDIT MASTER TITLE STYLE 2019 Projected 2018 Projected % Operating Expense + Income Taxes Increase/(Decrease) Amount Amount Variance Operation & Maintenance Expenses $34,517,333 $32,932,996 1,584,337 Administrative & General Expenses 40,931,609 40,262,946 668,663 Depreciation Expense 63,656,976 60,100,000 3,556,976 Taxes Other Than Income Taxes 19,538,270 14,789,000 4,749,270 Income Taxes 77,216,673 69,304,256 7,912,417 Total Operating Expenses + Income Taxes* 8% $235,860,861 $217,389,198 $18,471,663 2019 Projected Projected Gross Revenue Requirement Amount 2019 Projected Allowed Return (from previous slide) $234,871,627 + Projected Operating Expenses + Income Taxes (above) 235,860,861 2019 Projected Gross Revenue Requirement before Revenue Credits & Offsets* $470,732,488 *Totals may not reconcile due to rounding

CLICK TO EDIT MASTER TITLE STYLE Step 6: Revenue Requirement after Revenue Credits & Offsets 2019 Projected 2018 Projected Gross Revenue Requirement & Revenue Credits & Offsets Increase/(Decrease) % Variance Amount Amount Gross Revenue Requirement before Revenue Credits & Offsets $470,732,488 $426,010,460 $44,722,028 Less: Attachment GG Revenue Requirement (Sch. 26) 21,459,998 21,934,993 (474,995) Less: Attachment MM Revenue Requirement (Sch. 26A) 94,216,225 65,676,228 28,539,997 Less: Point-to-Point/Other Transmission Service Revenues 13,936,404 14,145,427 (209,023) Less: Rental Revenues 2,056,865 2,184,120 (127,255) Total Revenue Credits & Offsets* $131,669,492 $103,940,768 $27,728,724 27% Total 2019 Projected Revenue Requirement after $339,062,996 $322,069,692 $16,993,304 5% Revenue Credits & Offsets* *Totals may not reconcile due to rounding

CLICK TO EDIT MASTER TITLE STYLE Step 7: Net Revenue Requirement after 2017 True-Up Net Revenue Requirement 2019 Projected Revenue Requirement after Revenue Credits & Offsets $339,062,996 (860,096) + 2017 True-up Adjustment under/(over) Recovery $338,202,900 2019 Projected Net Revenue Requirement (including 2017 True-up Adjustment) *Totals may not reconcile due to rounding

CLICK TO EDIT MASTER TITLE STYLE Questions? 85

CLICK TO EDIT MASTER TITLE STYLE New Projects Submitted to MTEP 2018 Jeff Eddy – Manager, Planning 86

CLICK TO EDIT MASTER TITLE STYLE Summary 19 new projects submitted for MTEP19 category “A” approval • 4 related to 34/69 conversion project (2022-2026) • 3 age and/or condition projects (2020-2022) • 1 asset management “blanket” budget (2022) • 1 small customer interconnection “blanket” budget(2022) • 9 customer interconnection projects (2019-2022) • 1 system capacity projects

CLICK TO EDIT MASTER TITLE STYLE Age and/or Condition New London 69kV Tap Rebuild • Portion of the Burlington North – Mediapolis 69kV circuit • 10.6 miles long tap • Long spans, no shield wire • Other portions of this circuit being rebuilt • MISO Project 15004

CLICK TO EDIT MASTER TITLE STYLE Age and/or Condition Huntwoods-Sawyer 69kV Rebuild • Portion of the Huntwoods – Sawyer 69kV circuit • Reroute due to difficult terrain • Rotting poles with no access • MISO Project 15024

CLICK TO EDIT MASTER TITLE STYLE Age and/or Condition Dysart-Traer 161kV Rebuild • 15.6 miles • Design of line coupled with SD conductor results in on-going performance/maintenance issues. • MISO Project #15455

CLICK TO EDIT MASTER TITLE STYLE Customer Connections Ottumwa Heights • 161/24 kV distribution substation • Two transformers • 161kV ring bus • MISO Project 15449

Customer Connections – 34/69 Conversion Related CLICK TO EDIT MASTER TITLE STYLE Clarence South Substation • MISO Project 15453 Anamosa White Fawn • MISO Project 15452 Walford Terry • MISO Project 15454 Solon Big Grove • MISO Project 15484 Toledo Central • MISO Project 15466

CLICK TO EDIT MASTER TITLE STYLE Customer Connections Asbury 161kV Breaker Additions • Dubuque, Iowa • Two transformers • MISO Project 15485

CLICK TO EDIT MASTER TITLE STYLE Customer Connections South Grandview 161kV Breaker Additions • Dubuque, Iowa • Two transformers • MISO Project 15486

CLICK TO EDIT MASTER TITLE STYLE Customer Connections Beaver Rock Terminal Addition • Comanche, Iowa • Add 69kV terminal to existing sub • CIPCO to construct new 69kV line • MISO Project 15450

CLICK TO EDIT MASTER TITLE STYLE 2019 – 2021 Planning Projects (non-conversion) Jeff Eddy – Manager, Planning

CLICK TO EDIT MASTER TITLE STYLE Northeast Iowa

CLICK TO EDIT MASTER TITLE STYLE Eastern Iowa

Eastern Iowa – Projects Overview CLICK TO EDIT MASTER TITLE STYLE Van Allen 69-12kV Substation

CLICK TO EDIT MASTER TITLE STYLE Southern Iowa