INTEGRATED RESOURCE PLANNING REPORT...• 0.92 per unit to 1.05 per unit in the post-contingency state following the occurrence of any operating condition in categories P1 through

2018-19 Integrated Resource Plan

INTEGRATED RESOURCE PLANNING REPORT

TO THE

INDIANA UTILITY REGULATORY COMMISSION

Appendix – Volume 3 (Public-Redacted)

Submitted Pursuant to

Commission Rule 170 IAC 4-7

July 1, 2019

2018-19 Integrated Resource Plan Appendix Vol. 3 (Redacted exhibits version)

Exhibit I FERC Form 715 – Redacted

Exhibit J Projected Fuel Costs – Redacted

Exhibit K Short Term Large Industrial Energy Models – Redacted

Exhibit L Long-Term Retail and Wholesale Forecast Models Data - Redacted

Exhibit M Short-Term and Long-Term Wholesale Energy Models

2018-19 Integrated Resource Plan Exhibit I FERC Form 715 – Redacted

1.2

FERC FORM 715

ANNUAL TRANSMISSION PLANNING AND EVALUATION REPORT Part 1: Identification and Certification

April 1, 2019

Transmitting Utility Name(s) (Collectively referred to as “AEP”)

Appalachian Power Company AEP Appalachian Transmission Company Indiana Michigan Power Company AEP Kentucky Transmission Company Kentucky Power Company AEP Indiana Michigan Transmission Company Kingsport Power Company AEP Ohio Transmission Company Ohio Power Company AEP West Virginia Transmission Company Wheeling Power Company

Transmitting Utility Mailing Address

Contact Person

Name

Title

American Electric Power 8500 Smiths Mill Road New Albany, OH 43054

Nicolas Koehler

Manager, East Transmission Planning

Fax

Certifying Official By affixing my signature I certify that the information supplied in this filing by my Transmitting Utility is accurate.

Signature Date:

Name Kamran Ali

Title Managing Director, Transmission Planning

DocuSign Envelope ID: 211D5C46-7DB2-4E80-8EBB-D6CDDD19DAFD

3/26/2019 | 3:06 PM EDT

2018-19 I&M IRP Confidential Exhibit I FERC Form 715 (Public Version)

Page 1 of 22

Critical Energy Infrastructure Information

FERC FORM 715 ANNUAL TRANSMISSION PLANNING AND EVALUATION REPORT

Part 2

Part 2 of Form 715 contains planning files that include all PJM utilities and requires special software to view. The files were intentionally excluded from I&M’s 2018-19 IRP filing.


Page 2 of 22


FERC FORM 715 ANNUAL TRANSMISSION PLANNING AND EVALUATION REPORT

Part 3

Part 3 of Form 715 contained AEP Transmission System Maps. The maps are CEII and intentionally excluded from I&M’s 2018-19 IRP filing.


Page 3 of 22


4. 1

AMERICAN ELECTRIC POWER – 2019 FILING

FERC FORM 715 – ANNUAL TRANSMISSION PLANNING AND EVALUATION REPORT

PART 4 – TRANSMISSION PLANNING RELIABILITY CRITERIA

Attached is a document entitled "The American Electric Power System Transmission Planning Criteria”. This document provides the criteria to test and assess the strength of AEP’s transmission system to meet its load serving responsibility and provides a description of transmission planning criteria for the AEP System.


Page 4 of 22


4. 2

Purpose This report presents an overview of AEP’s transmission planning criteria. The AEP criteria described herein supplements the: 1) North American Electric Reliability Corporation (NERC) Reliability Standards; 2) ReliabilityFirst Corporation (RFC) Standards, 3) PJM Planning and Operating Manuals: Manual 14B, 4) SPP Criteria with Appendices Section 3, Regional Transmission Planning, 5) ERCOT Planning Guide Section 4, Transmission Planning Criteria where applicable, and 6) Midwest ISO Multi-Value Project (MVP). Nominal Voltage Levels Nominal 765 kV, 345 kV, 161 kV, and 138 kV voltage levels will normally be used for most new power transmission lines and are considered Bulk Electric System (BES). Some interconnection lines may be at 500 kV, 230 kV, or 115 kV to match neighboring utilities’ voltage, and some 69 kV lines may be constructed in appropriate situations. The AEP transmission facilities for the PJM region are divided into the following three performance categories:

• EHV Facilities: Transmission lines rated 765 kV, 500 kV, and 345 kV, and transformers with secondary voltages at or above 345 kV, are considered Extra High Voltage (EHV) facilities, and are referred to as “EHV facilities” in this document. These facilities are part of the BES.

• HV Facilities:

Transmission lines rated 230 kV, 161 kV, and 138 kV, and transformers with secondary voltages above 100 kV but below 345 kV, are considered High Voltage (HV) facilities, and are referred to as “HV facilities” in this document. These facilities are part of the BES.

• Sub-T Facilities:

Transmission lines rated below 100 kV, and transformers with secondary voltages below 100 kV are considered sub-transmission (Sub-T) facilities, and are referred to as “Sub-T facilities” in this document. These facilities are not part of the BES.

Voltage Limits For the SPP and ERCOT Regions: Transmission level buses above 60 kV shall meet the following steady state voltage response and post-contingency voltage deviation criteria:

• 0.95 per unit to 1.05 per unit in the pre-contingency state following the occurrence of any operating condition in category P0 of the NERC Reliability Standard TPL-001-4 addressing Transmission System Planning Performance Requirements. Facilities associated with series line compensating capacitors are permitted to operate above 1.05


Page 5 of 22


http://www.nerc.com/_layouts/PrintStandard.aspx?standardnumber=TPL-001-4&title=Transmission%20System%20Planning%20Performance%20Requirements&jurisdiction=United

4. 3

per unit.

• 0.92 per unit to 1.05 per unit in the post-contingency state following the occurrence of any operating condition in categories P1 through P7 of the NERC Reliability Standard TPL-001-4 addressing Transmission System Planning Performance Requirements. Facilities associated with series line compensating capacitors are permitted to operate above 1.05 per unit.

• Following the occurrence of any operating condition in categories P1 through P7 of the NERC Reliability Standard TPL-001-4, further analysis is required in the event of a post-contingency steady-state voltage deviation that exceeds 8% at any load-serving bus above 100 kV, exclusive of buses on a radial system that serve only Resource Entities and/or Load.

For the PJM and MISO Regions: Transmission level buses shall meet the following steady state voltage response and post-contingency voltage deviation criteria:

• 0.95 per unit to 1.05 per unit in the pre-contingency state following the occurrence of any operating condition in category P0 of the NERC Reliability Standard TPL-001-4 addressing Transmission System Planning Performance Requirements. Certain 500 kV facilities are permitted to operate above 1.05 per unit to match neighboring utilities operating criteria.

• 0.92 per unit to 1.05 per unit in the post-contingency state following the occurrence of any operating condition in categories P1 through P7 of the NERC Reliability Standard TPL-001-4 addressing Transmission System Planning Performance Requirements. Certain 500 kV facilities are permitted to operate above 1.05 per unit to match neighboring utilities operating criteria.

• Following the occurrence of any operating condition in categories P1 through P7 of the NERC Reliability Standard TPL-001-4, a voltage deviation from system normal of 8% or greater is not acceptable at any station.

Transmission voltages during emergencies should not result in customer voltages exceeding or falling below prescribed limits at distribution substations on the transmission system and voltages at generating stations below minimum acceptable levels established for each station must be avoided to prevent tripping of the generating units. Static and dynamic reactive devices and LTC auto-transformers are used in transmission substations to hold voltage levels within acceptable ranges during normal and emergency conditions. The voltage limits of these reactive devices can exceed prescribed limits if distribution regulating equipment maintains customer voltage within acceptable limits. Voltage fluctuations (flicker) are addressed in the AEP Interconnection Guidelines. Thermal Limits Thermal ratings define transmission facility loading limits. Normal ratings are generally based upon no abnormal loss of facility life or equipment damage. Emergency ratings accept some loss of life or strength, over a defined time limit for operation at the rated loading level. The thermal


Page 6 of 22


http://www.nerc.com/_layouts/PrintStandard.aspx?standardnumber=TPL-001-4&title=Transmission%20System%20Planning%20Performance%20Requirements&jurisdiction=Unitedhttp://www.nerc.com/_layouts/PrintStandard.aspx?standardnumber=TPL-001-4&title=Transmission%20System%20Planning%20Performance%20Requirements&jurisdiction=Unitedhttp://www.nerc.com/_layouts/PrintStandard.aspx?standardnumber=TPL-001-4&title=Transmission%20System%20Planning%20Performance%20Requirements&jurisdiction=Unitedhttp://www.nerc.com/_layouts/PrintStandard.aspx?standardnumber=TPL-001-4&title=Transmission%20System%20Planning%20Performance%20Requirements&jurisdiction=Unitedhttp://www.nerc.com/_layouts/PrintStandard.aspx?standardnumber=TPL-001-4&title=Transmission%20System%20Planning%20Performance%20Requirements&jurisdiction=United

4. 4

rating for a transmission line is defined by the most limiting element, be it a conductor capability, sag clearance, or terminal equipment rating. Thermal limits establish the maximum amount of electrical current that a transmission circuit or electrical facility can conduct over a specified time period before it sustains permanent damage by overheating or before it violates public safety requirements. Normal and emergency transmission equipment ratings are documented by AEP standards and guidelines. For the SPP and ERCOT Regions: Transmission level buses above 60 kV shall meet the following performance criteria:

• No facility may exceed its normal rating in the pre-contingency state following the occurrence of any operating condition in category P0 of the NERC Reliability Standard TPL-001-4 addressing Transmission System Planning Performance Requirements.

• No facility may exceed its emergency rating in the post-contingency state following the occurrence of any operating condition in categories P1 through P7 of the NERC Reliability Standard TPL-001-4 addressing Transmission System Planning Performance Requirements.

For the PJM and MISO Regions: Transmission level buses shall meet the following performance criteria:

• No facility may exceed its normal rating in the pre-contingency state following the occurrence of any operating condition in category P0 of the NERC Reliability Standard TPL-001-4 addressing Transmission System Planning Performance Requirements.

• No facility may exceed its emergency rating in the post-contingency state following the occurrence of any operating condition in categories P1 through P7 of the NERC Reliability Standard TPL-001-4 addressing Transmission System Planning Performance Requirements.

Steady State Testing Criteria The AEP transmission system will be designed so that there are no thermal or voltage criteria violations for a maintenance outage followed by an unscheduled outage of any transmission element during off-peak load periods. In general, load shedding is not permitted to maintain facilities within thermal and voltage limits. For the ERCOT Region: Steady State testing of the AEP transmission system is in accordance with NERC Reliability Standard TPL-001-4 and the ERCOT Planning Guide Section 4. For the MISO, PJM and SPP Regions: Steady State testing of the AEP transmission system is in accordance with NERC Reliability Standard TPL-001-4.


Page 7 of 22


http://www.nerc.com/_layouts/PrintStandard.aspx?standardnumber=TPL-001-4&title=Transmission%20System%20Planning%20Performance%20Requirements&jurisdiction=Unitedhttp://www.nerc.com/_layouts/PrintStandard.aspx?standardnumber=TPL-001-4&title=Transmission%20System%20Planning%20Performance%20Requirements&jurisdiction=Unitedhttp://www.nerc.com/_layouts/PrintStandard.aspx?standardnumber=TPL-001-4&title=Transmission%20System%20Planning%20Performance%20Requirements&jurisdiction=Unitedhttp://www.nerc.com/_layouts/PrintStandard.aspx?standardnumber=TPL-001-4&title=Transmission%20System%20Planning%20Performance%20Requirements&jurisdiction=Unitedhttp://www.nerc.com/_layouts/PrintStandard.aspx?standardnumber=TPL-001-4&title=Transmission%20System%20Planning%20Performance%20Requirements&jurisdiction=Unitedhttp://www.nerc.com/_layouts/PrintStandard.aspx?standardnumber=TPL-001-4&title=Transmission%20System%20Planning%20Performance%20Requirements&jurisdiction=United

4. 5

Short Circuit Testing Criteria For the SPP and ERCOT Regions: AEP steady state planning criteria requires that no bus voltage on AEP system shall exceed 1.05 per unit under system normal or contingency conditions. This voltage limit takes into consideration the equipment capabilities on AEP system. Short circuit assessment is performed assuming 1.05 per unit voltage at all the AEP system buses. For the MISO and PJM Regions: AEP steady state planning criteria requires that no bus voltage on AEP system shall exceed 1.05 per unit under system normal or contingency conditions. This voltage limit takes into consideration the equipment capabilities on AEP system. Short circuit assessment is performed assuming 1.05 per unit voltage at all the AEP system buses. This is a conservative approach but accounts for a wide range of system conditions. Circuit breakers at or near a generator plant shall be analyzed differently based on the scheduled voltage at the generator bus. This exception only applies to generator plants already in operation with established scheduled voltages. Stability Testing and Generation Ride-Through Performance Criteria Stability testing of the AEP transmission system is in accordance with NERC TPL-001-4. In addition, testing of the AEP system in the ERCOT Region is in accordance with the ERCOT Planning Guide Section 4. TPL-001-4 R4.1.3 acceptable damping and R5 transient voltage response criteria may be found in PJM Manual 14B Section G.2.2, ERCOT Planning Guide Sections 4.1.1.5 and 4.1.1.6, and the SPP Disturbance Performance Requirements document for the PJM, ERCOT, and SPP areas, respectively. An exception to TPL-001-4 stability testing criteria is that P7 category Planning Events are simulated with three-phase faults instead of phase-to-ground faults because three-phase is more conservative for common tower structure outages. All transmission and sub-transmission connected generation, including wind and solar projects, are required to maintain stability and continuity of real and reactive power delivery through all TPL-001-4 planning events. ERCOT generation is further required to abide by the low and high voltage ride-through requirements of Nodal Operating Guide Section 2.9. Generation that becomes radial through a series capacitor bank or multiple series capacitor banks may be exposed to RMS voltages greater than NERC PRC-024 and RTO criteria for High-Voltage Ride-Through (HVRT) no-trip zone levels because of natural system resonance. If such a radial configuration can result from N-1 or N-2 transmission outages, the generation must remain connected and producing power for the duration of such configuration even if voltages exceed the HVRT no-trip zone boundaries. An HVRT ride-through waver will be granted only under the following conditions:


Page 8 of 22


4. 6

1. Any SSR or SSCI resulting from the radial configuration is effectively mitigated, and 2. The potential loss of generation does not exceed the largest single unit in the

interconnection, and 3. N-3 or greater configuration is necessary for the generation to become radial to a series

capacitor, and 4. Agreed to by the RTO.


Page 9 of 22


5.1

AMERICAN ELECTRIC POWER – 2019 FILING

FERC FORM 715 – ANNUAL TRANSMISSION PLANNING AND EVALUATION REPORT

PART 5 – TRANSMISSION PLANNING ASSESSMENT PRACTICES EASTERN AEP

On an annual basis, AEP develops base case power flow models for the eastern AEP transmission system, representing the summer peak, winter peak, off-peak and light load conditions. These models are developed to represent the composite transmission/generation system into the future, although not for every year or season.

On an as-needed basis, AEP performs system reliability studies for the eastern AEP operating companies to determine future system needs. Such studies analyze the effect of single contingency outages of transmission lines, transformers, and generation units. In addition, the effects of less probable contingencies are also analyzed. These less probable contingencies involve outages such as loss of all generating units at a station, loss of all transmission lines on a common right-of-way, and other events resulting in loss of two or more components. If violations of the Planning Criteria are identified by the studies, alternative solutions are developed and analyzed. The recommended alternative plan then becomes part of the AEP 10-year Transmission Plan. Similar studies are also conducted by PJM in the process of developing the PJM Regional Transmission Expansion Plan (RTEP).

In performing such studies, AEP follows the practices outlined in the NERC Reliability Standards, the ReliabilityFirst Reliability Standards, and the AEP Transmission Planning Criteria described in Part 4.

The following section addresses Operating Procedures, providing documentation and modeling techniques that are employed by AEP in the assessment of transmission system performance.


Page 10 of 22


5.2

OPERATING PROCEDURES For operational planning, emergency ratings are used to assess performance following single contingencies but before any applicable operating procedures are implemented. Following an outage, system operators will implement available operating procedures in order to reduce all facility loadings below their respective normal ratings and projected contingency loadings below emergency ratings, per the PJM Manual for Transmission Operations (M03). This Operating Procedures section provides documentation of procedures which enhance the performance of the transmission system and mitigate problems that have previously been identified. These operating procedures are expected to be applicable for the foreseeable future. As a result, these operating procedures are to be in effect in screening studies that evaluate future system performance. The procedures described herein, all of which result in changes in network configuration or generation dispatch levels, are implemented to satisfy one or more of the following conditions:

1. To reduce facility loadings to within equipment thermal capabilities; 2. To maintain acceptable transient stability margins at generating stations; 3. To maintain area reliability without exceeding the short circuit capabilities of circuit

breakers; 4. To ensure that adequate voltage levels or steady state stability margins are maintained.


Page 11 of 22



Page 12 of 22



Page 13 of 22



Page 14 of 22



Page 15 of 22



Page 16 of 22



Page 17 of 22



Page 18 of 22



Page 19 of 22



Page 20 of 22



Page 21 of 22



Page 22 of 22


2018-19 Integrated Resource Plan Exhibit J Projected Fuel Costs – Redacted

Exhibit J Projected Fuel Costs

Confidential

Year Donald C. Cook 1 Donald C. Cook Rockport 1 Rockport 22019 61.3 56.4 224.3 224.32020 50.0 42.8 226.3 226.32021 44.7 41.1 231.0 231.02022 45.5 40.6 234.1 234.12023 46.2 41.8 242.2 242.22024 47.6 43.5 249.5 249.52025 48.7 44.6 256.7 256.72026 50.1 45.3 264.9 264.92027 54.4 48.0 274.1 274.12028 57.7 49.9 279.9 279.92029 59.6 52.9 292.8 292.82030 61.9 54.8 300.8 300.82031 60.9 55.7 303.7 303.72032 62.3 56.9 310.8 310.82033 63.6 58.1 319.2 319.22034 54.0 59.4 332.8 332.82035 0.0 60.7 341.3 341.32036 0.0 62.0 349.5 349.52037 0.0 63.3 363.2 363.22038 0.0 0.0 372.1 372.12039 0.0 0.0 381.1 381.12040 0.0 0.0 390.4 390.42041 0.0 0.0 400.0 400.02042 0.0 0.0 409.7 409.72043 0.0 0.0 419.6 419.62044 0.0 0.0 429.8 429.82045 0.0 0.0 440.3 440.32046 0.0 0.0 450.9 450.92047 0.0 0.0 461.8 461.82048 0.0 0.0 473.0 473.0

Indiana Michigan Power CompanyProjected Fuel Costs

¢/Mbtu

2018-19 I&M IRP Confidential Exhibit J (Public Version)

Projected Fuel Costs Page 1 of 1

2018-19 Integrated Resource Plan Exhibit K Short Term Large Industrial Energy Models – Redacted

CONFIDENTIAL (REDACTED)

Exhibit K

SHORT-TERM LARGE INDUSTRIAL ENERGY MODELS

AND INPUT DATA

2018-19 I&M IRP Confidential Exhibit K (Public Version) Short term Large Industrial Energy Models

Page 1 of 912

Indiana Michigan Power Company-Indiana and Michigan Large Industrial Customers

Input Data Glossary

Acct. No. – Customer Account Number kWh-Energy (kilowatt-hours) time-trend hi1-binary variable hi2-binary variable hi3-binary variable hi4-binary variable uni1-binary variable uni2-binary variable gi1-binary variable gi2-binary variable gi3-binary variable sd1-binary variable sd2-binary variable sd3-binary variable sd4-birnary variable air1-binary variable air2-binary variable air3-binary variable air4-birnary variable air5-birnary variable new1-binary variable new2-binary variable new3-binary variable new4-binary variable intk1-binary variable intk2-binary variable intk3-binary variable st1-binary variable st2-binary variable st3-binary variable st4-binary variable st5-binary variable boc1-binary variable boc2-binary variable ge1-binary variable ge2-binary variable min1-binary variable eng1-binary variable


Page 2 of 912

Indiana Michigan Power Company-Indiana and Michigan Large Industrial Customers

Input Data Glossary (Continued) lud1-binary variable dock1-binary variable dock2-bianry variable amer1-binary variable amer2-binary variable


Page 3 of 912

Indiana Michigan Po

wer Com

pany

‐ Indiana

Short‐Term

Large Indu

stria

l Ene

rgy Mod

els Inp

ut Data

year

mon

thacctNO

time

_TYPE_

_FRE

Q_

KWH

hi1

hi2

hi3

hi4

uni1

uni2

1997

11Nov

‐97

71

4326

400

00

00

00

1997

11Nov

‐97

71

1582

5600

00

00

00

1997

12De

c‐97

71

6986

6118

00

00

00

1997

12De

c‐97

71

6384

000

00

00

00

1997

12De

c‐97

71

3397

8000

00

00

00

1997

12De

c‐97

71

5171

200

00

00

00

1997

12De

c‐97

71

1493

5200

00

00

00

1998

1Jan‐98

71

4576

000

00

00

00

1998

2Feb‐98

71

1552

3200

00

00

00

1998

3Mar‐98

71

6768

000

00

00

00

1998

3Mar‐98

71

1043

7000

00

00

00

1998

4Ap

r‐98

71

6900

000

00

00

00

1998

4Ap

r‐98

71

1119

3000

00

00

00

1998

4Ap

r‐98

71

3479

7000

00

00

00

1998

5May‐98

71

7140

000

00

00

00

1998

5May‐98

71

1017

4500

00

00

00

1998

6Jun‐98

71

1585

9446

00

00

00

1998

6Jun‐98

71

1167

6000

00

00

00

1998

7Jul‐9

87

131

8570

000

00

00

019

987

Jul‐9

87

10

00

00

00

1998

8Au

g‐98

71

8460

000

00

00

00

1998

9Sep‐98

71

1202

2500

00

00

00

1998

10Oct‐98

71

5527

256

00

00

00

1998

11Nov

‐98

71

7752

000

00

00

00

1998

11Nov

‐98

71

1214

8500

00

00

00

1998

11Nov‐98

71

3595

2000

00

00

00

1998

11Nov

‐98

71

7503

644

00

00

00

1998

12De

c‐98

71

7116

000

00

00

00

1998

12De

c‐98

71

3609

9000

00

00

00

1999

1Jan‐99

71

5904

000

00

00

00

1999

1Jan‐99

71

8808

000

00

00

00

1999

1Jan‐99

71

6782

813

00

00

00

1999

1Jan‐99

71

7228

7208

00

00

00

1999

1Jan‐99

71

6888

000

00

00

00


Page 4 of 912

Indiana Michigan Po

wer Com

pany

‐ Indiana

Short‐Term

Large Indu

stria

l Ene

rgy Mod

els Inp

ut Data

year

mon

thacctNO

time

_TYPE_

_FRE

Q_

KWH

hi1

hi2

hi3

hi4

uni1

uni2

1999

1Jan‐99

71

1205

4000

00

00

00

1999

1Jan‐99

71

6422

400

00

00

00

1999

1Jan‐99

71

3465

0000

00

00

00

1999

1Jan‐99

71

8390

400

00

00

00

1999

1Jan‐99

71

1585

9200

00

00

00

1999

2Feb‐99

71

6798

726

00

00

00

1999

2Feb‐99

71

9912

000

00

00

00

1999

2Feb‐99

71

6653

768

00

00

00

1999

2Feb‐99

71

1.10

E+08

00

00

00

1999

2Feb‐99

71

6552

000

00

00

00

1999

2Feb‐99

71

8140

800

00

00

00

1999

2Feb‐99

71

3339

0000

00

00

00

1999

2Feb‐99

71

8313

600

00

00

00

1999

2Feb‐99

71

1483

4400

00

00

00

1999

3Mar‐99

71

6983

540

00

00

00

1999

3Mar‐99

71

9216

000

00

00

00

1999

3Mar‐99

71

7572

284

00

00

00

1999

3Mar‐99

71

1.29

E+08

00

00

00

1999

3Mar‐99

71

7392

000

00

00

00

1999

3Mar‐99

71

1281

0000

00

00

00

1999

3Mar‐99

71

8889

600

00

00

00

1999

3Mar‐99

71

3511

2000

00

00

00

1999

3Mar‐99

71

9833

600

00

00

00

1999

3Mar‐99

71

1668

2400

00

00

00

1999

4Ap

r‐99

71

5380

328

00

00

00

1999

4Ap

r‐99

71

9408

000

00

00

00

1999

4Ap

r‐99

71

7612

744

00

00

00

1999

4Ap

r‐99

71

1.27

E+08

00

00

00

1999

4Ap

r‐99

71

7428

000

00

00

00

1999

4Ap

r‐99

71

1276

8000

00

00

00

1999

4Ap

r‐99

71

8419

200

00

00

00

1999

4Ap

r‐99

71

3378

9000

00

00

00

1999

4Ap

r‐99

71

9094

400

00

00

00

1999

4Ap

r‐99

71

1627

9200

00

00

00


Page 5 of 912

Indiana Michigan Po

wer Com

pany

‐ Indiana

Short‐Term

Large Indu

stria

l Ene

rgy Mod

els Inp

ut Data

year

mon

thacctNO

time

_TYPE_

_FRE

Q_

KWH

hi1

hi2

hi3

hi4

uni1

uni2

1999

5May‐99

71

5548

419

00

00

00

1999

5May‐99

71

8808

000

00

00

00

1999

5May‐99

71

6919

948

00

00

00

1999

5May‐99

71

1.27

E+08

00

00

00

1999

5May‐99

71

1478

4000

00

00

00

1999

5May‐99

71

7766

400

00

00

00

1999

5May‐99

71

3654

0000

00

00

00

1999

5May‐99

71

8953

600

00

00

00

1999

5May‐99

71

1663

2000

00

00

00

1999

6Jun‐99

71

6851

967

00

00

00

1999

6Jun‐99

71

1036

8000

00

00

00

1999

6Jun‐99

71

7427

711

00

00

00

1999

6Jun‐99

71

1.07

E+08

00

00

00

1999

6Jun‐99

71

8592

000

00

00

00

1999

6Jun‐99

71

1485

7500

00

00

00

1999

6Jun‐99

71

8380

800

00

00

00

1999

6Jun‐99

71

3418

8000

00

00

00

1999

6Jun‐99

71

9756

800

00

00

00

1999

6Jun‐99

71

1431

3600

00

00

00

1999

7Jul‐9

97

166

7200

00

00

00

019

997

Jul‐9

97

110

0320

000

00

00

019

997

Jul‐9

97

167

5193

70

00

00

019

997

Jul‐9

97

11.15

E+08

00

00

00

1999

7Jul‐9

97

185

9200

00

00

00

019

997

Jul‐9

97

114

7840

000

00

00

019

997

Jul‐9

97

172

2880

00

00

00

019

997

Jul‐9

97

134

6920

000

00

00

019

997

Jul‐9

97

188

0960

00

00

00

019

997

Jul‐9

97

115

1032

000

00

00

019

998

Aug‐99

71

7019

706

00

00

00

1999

8Au

g‐99

71

9480

000

00

00

00

1999

8Au

g‐99

71

7379

689

00

00

00

1999

8Au

g‐99

71

1.28

E+08

00

00

00

1999

8Au

g‐99

71

8448

000

00

00

00


Page 6 of 912

Indiana Michigan Po

wer Com

pany

‐ Indiana

Short‐Term

Large Indu

stria

l Ene

rgy Mod

els Inp

ut Data

year

mon

thacctNO

time

_TYPE_

_FRE

Q_

KWH

hi1

hi2

hi3

hi4

uni1

uni2

1999

8Au

g‐99

71

8043

000

00

00

00

1999

8Au

g‐99

71

8160

000

00

00

00

1999

8Au

g‐99

71

3475

2702

00

00

00

1999

8Au

g‐99

71

1010

5600

00

00

00

1999

8Au

g‐99

71

1624

5600

00

00

00

1999

9Sep‐99

71

6489

176

00

00

00

1999

9Sep‐99

71

1060

8000

00

00

00

1999

9Sep‐99

71

7169

945

00

00

00

1999

9Sep‐99

71

1.27

E+08

00

00

00

1999

9Sep‐99

71

7701

274

00

00

00

1999

9Sep‐99

71

1449

0000

00

00

00

1999

9Sep‐99

71

8553

600

00

00

00

1999

9Sep‐99

71

3639

3000

00

00

00

1999

9Sep‐99

71

9270

400

00

00

00

1999

9Sep‐99

71

1594

3200

00

00

00

1999

10Oct‐99

71

6984

175

00

00

00

1999

10Oct‐99

71

9264

000

00

00

00

1999

10Oct‐99

71

7564

382

00

00

00

1999

10Oct‐99

71

1.27

E+08

00

00

00

1999

10Oct‐99

71

8076

000

00

00

00

1999

10Oct‐99

71

8995

200

00

00

00

1999

10Oct‐99

71

3269

7000

00

00

00

1999

10Oct‐99

71

8880

000

00

00

00

1999

10Oct‐99

71

1644

7200

00

00

00

1999

11Nov

‐99

71

8300

637

00

00

00

1999

11Nov

‐99

71

9408

000

00

00

00

1999

11Nov

‐99

71

7040

956

00

00

00

1999

11Nov

‐99

71

1.29

E+08

00

00

00

1999

11Nov

‐99

71

6930

641

00

00

00

1999

11Nov

‐99

71

8313

600

00

00

00

1999

11Nov

‐99

71

3614

1000

00

00

00

1999

11Nov

‐99

71

6956

800

00

00

00

1999

11Nov

‐99

71

1611

120

00

00

00

1999

12De

c‐99

71

7128

000

00

00

00


Page 7 of 912

Indiana Michigan Po

wer Com

pany

‐ Indiana

Short‐Term

Large Indu

stria

l Ene

rgy Mod

els Inp

ut Data

year

mon

thacctNO

time

_TYPE_

_FRE

Q_

KWH

hi1

hi2

hi3

hi4

uni1

uni2

1999

12De

c‐99

71

1046

4000

00

00

00

1999

12De

c‐99

71

6840

723

00

00

00

1999

12De

c‐99

71

1.04

E+08

00

00

00

1999

12De

c‐99

71

7236

000

00

00

00

1999

12De

c‐99

71

1482

6000

00

00

00

1999

12De

c‐99

71

1025

2800

00

00

00

1999

12De

c‐99

71

3439

8000

00

00

00

1999

12De

c‐99

71

7593

600

00

00

00

1999

12De

c‐99

71

1612

8000

00

00

00

2000

1Jan‐00

71

7440

000

00

00

00

2000

1Jan‐00

71

9384

000

00

00

00

2000

1Jan‐00

71

6840

723

00

00

00

2000

1Jan‐00

71

00

00

00

2000

1Jan‐00

71

1.34

E+08

00

00

00

2000

1Jan‐00

71

6984

000

00

00

00

2000

1Jan‐00

71

1520

4000

00

00

00

2000

1Jan‐00

71

8486

400

00

00

00

2000

1Jan‐00

71

00

00

00

2000

1Jan‐00

71

3540

6000

00

00

00

2000

1Jan‐00

71

9161

600

00

00

00

2000

1Jan‐00

71

1503

6000

00

00

00

2000

2Feb‐00

71

7824

000

00

00

00

2000

2Feb‐00

71

9864

000

00

00

00

2000

2Feb‐00

71

7104

728

00

00

00

2000

2Feb‐00

71

00

00

00

2000

2Feb‐00

71

1.26

E+08

00

00

00

2000

2Feb‐00

71

6804

000

00

00

00

2000

2Feb‐00

71

1424

8500

00

00

00

2000

2Feb‐00

71

8294

400

00

00

00

2000

2Feb‐00

71

00

00

00

2000

2Feb‐00

71

3481

8000

00

00

00

2000

2Feb‐00

71

00

00

00

2000

2Feb‐00

71

9388

800

00

00

00

2000

2Feb‐00

71

1468

3200

00

00

00


Page 8 of 912

Indiana Michigan Po

wer Com

pany

‐ Indiana

Short‐Term

Large Indu

stria

l Ene

rgy Mod

els Inp

ut Data

year

mon

thacctNO

time

_TYPE_

_FRE

Q_

KWH

hi1

hi2

hi3

hi4

uni1

uni2

2000

3Mar‐00

71

8100

000

00

00

00

2000

3Mar‐00

71

9216

000

00

00

00

2000

3Mar‐00

71

6863

130

00

00

00

2000

3Mar‐00

71

00

00

00

2000

3Mar‐00

71

1.41

E+08

00

00

00

2000

3Mar‐00

71

7536

000

00

00

00

2000

3Mar‐00

71

1462

6500

00

00

00

2000

3Mar‐00

71

8832

000

00

00

00

2000

3Mar‐00

71

00

00

00

2000

3Mar‐00

71

3570

0000

00

00

00

2000

3Mar‐00

71

00

00

00

2000

3Mar‐00

71

9894

400

00

00

00

2000

3Mar‐00

71

1666

5600

00

00

00

2000

4Ap

r‐00

71

7488

000

00

00

00

2000

4Ap

r‐00

71

9312

000

00

00

00

2000

4Ap

r‐00

71

7838

108

00

00

00

2000

4Ap

r‐00

71

00

00

00

2000

4Ap

r‐00

71

1.16

E+08

00

00

00

2000

4Ap

r‐00

71

7140

000

00

00

00

2000

4Ap

r‐00

71

1381

8000

00

00

00

2000

4Ap

r‐00

71

8467

200

00

00

00

2000

4Ap

r‐00

71

00

00

00

2000

4Ap

r‐00

71

3141

6000

00

00

00

2000

4Ap

r‐00

71

00

00

00

2000

4Ap

r‐00

71

8854

400

00

00

00

2000

4Ap

r‐00

71

1632

9600

00

00

00

2000

5May‐00

71

7656

000

00

00

00

2000

5May‐00

71

9576

000

00

00

00

2000

5May‐00

71

6364

357

00

00

00

2000

5May‐00

71

00

00

00

2000

5May‐00

71

1.38

E+08

00

00

00

2000

5May‐00

71

7956

000

00

00

00

2000

5May‐00

71

1500

4500

00

00

00

2000

5May‐00

71

8150

400

00

00

00


Page 9 of 912

Indiana Michigan Po

wer Com

pany

‐ Indiana

Short‐Term

Large Indu

stria

l Ene

rgy Mod

els Inp

ut Data

year

mon

thacctNO

time

_TYPE_

_FRE

Q_

KWH

hi1

hi2

hi3

hi4

uni1

uni2

2000

5May‐00

71

00

00

00

2000

5May‐00

71

3530

1000

00

00

00

2000

5May‐00

71

00

00

00

2000

5May‐00

71

1030

0800

00

00

00

2000

5May‐00

71

1634

6400

00

00

00

2000

6Jun‐00

71

7200

000

00

00

00

2000

6Jun‐00

71

1022

4000

00

00

00

2000

6Jun‐00

71

7274

559

00

00

00

2000

6Jun‐00

71

00

00

00

2000

6Jun‐00

71

1.27

E+08

00

00

00

2000

6Jun‐00

71

8040

000

00

00

00

2000

6Jun‐00

71

1557

1500

00

00

00

2000

6Jun‐00

71

9120

000

00

00

00

2000

6Jun‐00

71

00

00

00

2000

6Jun‐00

71

3555

3000

00

00

00

2000

6Jun‐00

71

00

00

00

2000

6Jun‐00

71

9040

000

00

00

00

2000

6Jun‐00

71

1597

6800

00

00

00

2000

7Jul‐0

07

168

2800

00

00

00

020

007

Jul‐0

07

198

8800

00

00

00

020

007

Jul‐0

07

177

6675

60

00

00

020

007

Jul‐0

07

10

00

00

020

007

Jul‐0

07

11.26

E+08

00

00

00

2000

7Jul‐0

07

178

9600

00

00

00

020

007

Jul‐0

07

116

0335

000

00

00

020

007

Jul‐0

07

179

2960

00

00

00

020

007

Jul‐0

07

10

00

00

020

007

Jul‐0

07

137

6950

000

00

00

020

007

Jul‐0

07

10

00

00

020

007

Jul‐0

07

196

7680

00

00

00

020

007

Jul‐0

07

115

2712

000

00

00

020

008

Aug‐00

71

8436

000

00

00

00

2000

8Au

g‐00

71

9504

000

00

00

00

2000

8Au

g‐00

71

6333

078

00

00

00


Page 10 of 912

Indiana Michigan Po

wer Com

pany

‐ Indiana

Short‐Term

Large Indu

stria

l Ene

rgy Mod

els Inp

ut Data

year

mon

thacctNO

time

_TYPE_

_FRE

Q_

KWH

hi1

hi2

hi3

hi4

uni1

uni2

2000

8Au

g‐00

71

00

00

00

2000

8Au

g‐00

71

1.09

E+08

00

00

00

2000

8Au

g‐00

71

8268

000

00

00

00

2000

8Au

g‐00

71

1496

2500

00

00

00

2000

8Au

g‐00

71

7190

400

00

00

00

2000

8Au

g‐00

71

00

00

00

2000

8Au

g‐00

71

3641

4000

00

00

00

2000

8Au

g‐00

71

00

00

00

2000

8Au

g‐00

71

9635

200

00

00

00

2000

8Au

g‐00

71

1617

8400

00

00

00

2000

9Sep‐00

71

8160

000

00

00

00

2000

9Sep‐00

71

1048

8000

00

00

00

2000

9Sep‐00

71

7669

782

00

00

00

2000

9Sep‐00

71

00

00

00

2000

9Sep‐00

71

1.18

E+08

00

00

00

2000

9Sep‐00

71

7752

000

00

00

00

2000

9Sep‐00

71

1470

0000

00

00

00

2000

9Sep‐00

71

9628

800

00

00

00

2000

9Sep‐00

71

00

00

00

2000

9Sep‐00

71

3620

4000

00

00

00

2000

9Sep‐00

71

00

00

00

2000

9Sep‐00

71

8956

800

00

00

00

2000

9Sep‐00

71

1464

9600

00

00

00

2000

10Oct‐00

71

9156

000

00

00

00

2000

10Oct‐00

71

9024

000

00

00

00

2000

10Oct‐00

71

7742

225

00

00

00

2000

10Oct‐00

71

00

00

00

2000

10Oct‐00

71

1.00

E+08

00

00

00

2000

10Oct‐00

71

7512

000

00

00

00

2000

10Oct‐00

71

1484

7000

00

00

00

2000

10Oct‐00

71

8592

000

00

00

00

2000

10Oct‐00

71

00

00

00

2000

10Oct‐00

71

3308

2912

00

00

00

2000

10Oct‐00

71

00

00

00


Page 11 of 912

Indiana Michigan Po

wer Com

pany

‐ Indiana

Short‐Term

Large Indu

stria

l Ene

rgy Mod

els Inp

ut Data

year

mon

thacctNO

time

_TYPE_

_FRE

Q_

KWH

hi1

hi2

hi3

hi4

uni1

uni2

2000

10Oct‐00

71

1029

4400

00

00

00

2000

10Oct‐00

71

1461

6000

00

00

00

2000

11Nov

‐00

71

7740

000

00

00

00

2000

11Nov

‐00

71

9264

000

00

00

00

2000

11Nov

‐00

71

7661

675

00

00

00

2000

11Nov

‐00

71

00

00

00

2000

11Nov

‐00

71

1.05

E+08

00

00

00

2000

11Nov

‐00

71

6756

000

00

00

00

2000

11Nov

‐00

71

1373

4000

00

00

00

2000

11Nov

‐00

71

8419

200

00

00

00

2000

11Nov

‐00

71

3304

3711

00

00

00

2000

11Nov

‐00

71

9468

800

00

00

00

2000

11Nov

‐00

71

1147

4400

00

00

00

2000

12De

c‐00

71

1029

6000

00

00

00

2000

12De

c‐00

71

7427

889

00

00

00

2000

12De

c‐00

71

00

00

00

2000

12De

c‐00

71

1015

6800

00

00

00

2000

12De

c‐00

71

2905

0942

00

00

00

2000

12De

c‐00

71

8476

800

00

00

00

2001

11‐Jan

71

8340

000

00

00

00

2001

11‐Jan

71

9792

000

00

00

00

2001

11‐Jan

71

6808

605

00

00

00

2001

11‐Jan

71

00

00

00

2001

11‐Jan

71

8534

400

00

00

00

2001

11‐Jan

71

2888

7535

00

00

00

2001

11‐Jan

71

9072

000

00

00

00

2001

21‐Feb

71

7572

000

00

00

00

2001

21‐Feb

71

9024

000

00

00

00

2001

21‐Feb

71

7564

288

00

00

00

2001

21‐Feb

71

00

00

00

2001

21‐Feb

71

1.17

E+08

00

00

00

2001

21‐Feb

71

6240

000

00

00

00

2001

21‐Feb

71

1295

7000

00

00

00

2001

21‐Feb

71

9062

400

00

00

00


Page 12 of 912

Indiana Michigan Po

wer Com

pany

‐ Indiana

Short‐Term

Large Indu

stria

l Ene

rgy Mod

els Inp

ut Data

year

mon

thacctNO

time

_TYPE_

_FRE

Q_

KWH

hi1

hi2

hi3

hi4

uni1

uni2

2001

21‐Feb

71

00

00

00

2001

21‐Feb

71

2923

2844

00

00

00

2001

21‐Feb

71

00

00

00

2001

21‐Feb

71

9549

552

00

00

00

2001

21‐Feb

71

1512

0000

00

00

00

2001

31‐Mar

71

9336

000

00

00

00

2001

31‐Mar

71

9048

000

00

00

00

2001

31‐Mar

71

7097

255

00

00

00

2001

31‐Mar

71

00

00

00

2001

31‐Mar

71

1.33

E+08

00

00

00

2001

31‐Mar

71

6792

000

00

00

00

2001

31‐Mar

71

1421

7000

00

00

00

2001

31‐Mar

71

8448

000

00

00

00

2001

31‐Mar

71

00

00

00

2001

31‐Mar

71

3175

6638

00

00

00

2001

31‐Mar

71

00

00

00

2001

31‐Mar

71

1074

0310

00

00

00

2001

31‐Mar

71

1537

2000

00

00

00

2001

41‐Ap

r7

176

9200

00

00

00

020

014

1‐Ap

r7

188

0800

00

00

00

020

014

1‐Ap

r7

180

6410

10

00

00

020

014

1‐Ap

r7

10

00

00

020

014

1‐Ap

r7

11.24

E+08

00

00

00

2001

41‐Ap

r7

167

1396

20

00

00

020

014

1‐Ap

r7

113

5284

230

00

00

020

014

1‐Ap

r7

176

1280

00

00

00

020

014

1‐Ap

r7

10

00

00

020

014

1‐Ap

r7

131

3900

400

00

00

020

014

1‐Ap

r7

10

00

00

020

014

1‐Ap

r7

111

1842

110

00

00

020

014

1‐Ap

r7

115

9621

210

00

00

020

015

1‐May

71

8556

000

00

00

00

2001

51‐May

71

9624

000

00

00

00

2001

51‐May

71

7050

065

00

00

00


Page 13 of 912

Indiana Michigan Po

wer Com

pany

‐ Indiana

Short‐Term

Large Indu

stria

l Ene

rgy Mod

els Inp

ut Data

year

mon

thacctNO

time

_TYPE_

_FRE

Q_

KWH

hi1

hi2

hi3

hi4

uni1

uni2

2001

51‐May

71

00

00

00

2001

51‐May

71

1.34

E+08

00

00

00

2001

51‐May

71

7085

315

00

00

00

2001

51‐May

71

1472

8241

00

00

00

2001

51‐May

71

6182

400

00

00

00

2001

51‐May

71

00

00

00

2001

51‐May

71

3360

6257

00

00

00

2001

51‐May

71

00

00

00

2001

51‐May

71

1104

3217

00

00

00

2001

51‐May

71

1544

8648

00

00

00

2001

61‐Jun

71

8352

000

00

00

00

2001

61‐Jun

71

9504

000

00

00

00

2001

61‐Jun

71

7896

131

00

00

00

2001

61‐Jun

71

00

00

00

2001

61‐Jun

71

1.33

E+08

00

00

00

2001

61‐Jun

71

7411

889

00

00

00

2001

61‐Jun

71

1552

3382

00

00

00

2001

61‐Jun

71

9638

400

00

00

00

2001

61‐Jun

71

00

00

00

2001

61‐Jun

71

3072

3316

00

00

00

2001

61‐Jun

71

00

00

00

2001

61‐Jun

71

1008

2343

00

00

00

2001

61‐Jun

71

1591

4080

00

00

00

2001

71‐Jul

71

6768

000

00

00

00

2001

71‐Jul

71

1010

4000

00

00

00

2001

71‐Jul

71

8089

834

00

00

00

2001

71‐Jul

71

00

00

00

2001

71‐Jul

71

1.23

E+08

00

00

00

2001

71‐Jul

71

7337

387

00

00

00

2001

71‐Jul

71

1558

7160

00

00

00

2001

71‐Jul

71

8294

400

00

00

00

2001

71‐Jul

71

00

00

00

2001

71‐Jul

71

3107

5891

00

00

00

2001

71‐Jul

71

00

00

00


Page 14 of 912

Indiana Michigan Po

wer Com

pany

‐ Indiana

Short‐Term

Large Indu

stria

l Ene

rgy Mod

els Inp

ut Data

year

mon

thacctNO

time

_TYPE_

_FRE

Q_

KWH

hi1

hi2

hi3

hi4

uni1

uni2

2001

71‐Jul

71

1150

3645

00

00

00

2001

71‐Jul

71

1466

6838

00

00

00

2001

81‐Au

g7

172

9600

00

00

00

020

018

1‐Au

g7

110

2000

000

00

00

020

018

1‐Au

g7

171

2367

50

00

00

020

018

1‐Au

g7

10

00

00

020

018

1‐Au

g7

11.23

E+08

00

00

00

2001

81‐Au

g7

179

2289

80

00

00

020

018

1‐Au

g7

115

1265

580

00

00

020

018

1‐Au

g7

184

1920

00

00

00

020

018

1‐Au

g7

10

00

00

020

018

1‐Au

g7

132

2918

190

00

00

020

018

1‐Au

g7

10

00

00

020

018

1‐Au

g7

111

0880

000

00

00

020

018

1‐Au

g7

116

0034

240

00

00

020

019

1‐Sep

71

6024

000

00

00

00

2001

91‐Sep

71

9216

000

00

00

00

2001

91‐Sep

71

8774

474

00

00

00

2001

91‐Sep

71

00

00

00

2001

91‐Sep

71

1.24

E+08

00

00

00

2001

91‐Sep

71

7046

175

00

00

00

2001

91‐Sep

71

1511

3895

00

00

00

2001

91‐Sep

71

9398

400

00

00

00

2001

91‐Sep

71

00

00

00

2001

91‐Sep

71

3328

8250

00

00

00

2001

91‐Sep

71

00

00

00

2001

91‐Sep

71

9804

204

00

00

00

2001

91‐Sep

71

1563

2886

00

00

00

2001

101‐Oct

71

7188

000

10

00

00

2001

101‐Oct

71

8040

000

10

00

00

2001

101‐Oct

71

7033

546

10

00

00

2001

101‐Oct

71

10

00

00

2001

101‐Oct

71

1.19

E+08

10

00

00

2001

101‐Oct

71

6991

959

10

00

00


Page 15 of 912

Indiana Michigan Po

wer Com

pany

‐ Indiana

Short‐Term

Large Indu

stria

l Ene

rgy Mod

els Inp

ut Data

year

mon

thacctNO

time

_TYPE_

_FRE

Q_

KWH

hi1

hi2

hi3

hi4

uni1

uni2

2001

101‐Oct

71

1507

2825

10

00

00

2001

101‐Oct

71

8457

600

10

00

00

2001

101‐Oct

71

10

00

00

2001

101‐Oct

71

3348

3959

10

00

00

2001

101‐Oct

71

10

00

00

2001

101‐Oct

71

1173

2722

10

00

00

2001

101‐Oct

71

1614

7782

10

00

00

2001

111‐Nov

71

5940

000

10

00

00

2001

111‐Nov

71

8328

000

10

00

00

2001

111‐Nov

71

8177

430

10

00

00

2001

111‐Nov

71

10

00

00

2001

111‐Nov

71

1.08

E+08

10

00

00

2001

111‐Nov

71

6397

052

10

00

00

2001

111‐Nov

71

1353

6889

10

00

00

2001

111‐Nov

71

9427

200

10

00

00

2001

111‐Nov

71

10

00

00

2001

111‐Nov

71

3009

7951

10

00

00

2001

111‐Nov

71

10

00

00

2001

111‐Nov

71

1071

4184

10

00

00

2001

111‐Nov

71

1433

2467

10

00

00

2001

121‐De

c7

159

1600

01

00

00

020

0112

1‐De

c7

192

6400

01

00

00

020

0112

1‐De

c7

179

4383

11

00

00

020

0112

1‐De

c7

11

00

00

020

0112

1‐De

c7

11.08

E+08

10

00

00

2001

121‐De

c7

159

9054

01

00

00

020

0112

1‐De

c7

114

0572

861

00

00

020

0112

1‐De

c7

194

6560

01

00

00

020

0112

1‐De

c7

11

00

00

020

0112

1‐De

c7

132

6416

151

00

00

020

0112

1‐De

c7

11

00

00

020

0112

1‐De

c7

110

2321

641

00

00

020

0112

1‐De

c7

116

0445

431

00

00

020

021

2‐Jan

71

7020

000

10

00

00


Page 16 of 912

Indiana Michigan Po

wer Com

pany

‐ Indiana

Short‐Term

Large Indu

stria

l Ene

rgy Mod

els Inp

ut Data

year

mon

thacctNO

time

_TYPE_

_FRE

Q_

KWH

hi1

hi2

hi3

hi4

uni1

uni2

2002

12‐Jan

71

7944

000

10

00

00

2002

12‐Jan

71

6341

971

10

00

00

2002

12‐Jan

71

10

00

00

2002

12‐Jan

71

1.27

E+08

10

00

00

2002

12‐Jan

71

6329

146

10

00

00

2002

12‐Jan

71

1491

1958

10

00

00

2002

12‐Jan

71

8880

000

10

00

00

2002

12‐Jan

71

10

00

00

2002

12‐Jan

71

3549

1371

10

00

00

2002

12‐Jan

71

10

00

00

2002

12‐Jan

71

1098

2741

10

00

00

2002

12‐Jan

71

1497

1484

10

00

00

2002

22‐Feb

71

5820

000

10

00

00

2002

22‐Feb

71

7446

000

10

00

00

2002

22‐Feb

71

8260

053

10

00

00

2002

22‐Feb

71

10

00

00

2002

22‐Feb

71

1.21

E+08

10

00

00

2002

22‐Feb

71

5878

793

10

00

00

2002

22‐Feb

71

1350

1201

10

00

00

2002

22‐Feb

71

8534

400

10

00

00

2002

22‐Feb

71

10

00

00

2002

22‐Feb

71

3221

7391

10

00

00

2002

22‐Feb

71

10

00

00

2002

22‐Feb

71

1026

5600

10

00

00

2002

22‐Feb

71

1473

8424

10

00

00

2002

32‐Mar

71

7680

000

10

00

00

2002

32‐Mar

71

7506

000

10

00

00

2002

32‐Mar

71

6467

654

10

00

00

2002

32‐Mar

71

10

00

00

2002

32‐Mar

71

1.35

E+08

10

00

00

2002

32‐Mar

71

6335

582

10

00

00

2002

32‐Mar

71

1559

1356

10

00

00

2002

32‐Mar

71

8841

600

10

00

00

2002

32‐Mar

71

10

00

00


Page 17 of 912

Indiana Michigan Po

wer Com

pany

‐ Indiana

Short‐Term

Large Indu

stria

l Ene

rgy Mod

els Inp

ut Data

year

mon

thacctNO

time

_TYPE_

_FRE

Q_

KWH

hi1

hi2

hi3

hi4

uni1

uni2

2002

32‐Mar

71

3605

3768

10

00

00

2002

32‐Mar

71

10

00

00

2002

32‐Mar

71

1044

1600

10

00

00

2002

32‐Mar

71

1653

4385

10

00

00

2002

42‐Ap

r7

178

1200

01

00

00

020

024

2‐Ap

r7

181

8400

01

00

00

020

024

2‐Ap

r7

179

6887

01

00

00

020

024

2‐Ap

r7

11

00

00

020

024

2‐Ap

r7

11.30

E+08

10

00

00

2002

42‐Ap

r7

163

9024

11

00

00

020

024

2‐Ap

r7

114

5213

381

00

00

020

024

2‐Ap

r7

186

6880

01

00

00

020

024

2‐Ap

r7

11

00

00

020

024

2‐Ap

r7

132

2973

261

00

00

020

024

2‐Ap

r7

11

00

00

020

024

2‐Ap

r7

112

4096

001

00

00

020

024

2‐Ap

r7

114

0798

501

00

00

020

025

2‐May

71

6900

000

10

00

00

2002

52‐May

71

7968

000

10

00

00

2002

52‐May

71

7815

135

10

00

00

2002

52‐May

71

10

00

00

2002

52‐May

71

1.25

E+08

10

00

00

2002

52‐May

71

6908

479

10

00

00

2002

52‐May

71

1521

3300

10

00

00

2002

52‐May

71

8227

200

10

00

00

2002

52‐May

71

10

00

00

2002

52‐May

71

3773

7000

10

00

00

2002

52‐May

71

10

00

00

2002

52‐May

71

1155

2000

10

00

00

2002

52‐May

71

1623

6226

10

00

00

2002

62‐Jun

71

6828

000

10

00

00

2002

62‐Jun

71

8232

000

10

00

00

2002

62‐Jun

71

8435

392

10

00

00

2002

62‐Jun

71

10

00

00


Page 18 of 912

Indiana Michigan Po

wer Com

pany

‐ Indiana

Short‐Term

Large Indu

stria

l Ene

rgy Mod

els Inp

ut Data

year

mon

thacctNO

time

_TYPE_

_FRE

Q_

KWH

hi1

hi2

hi3

hi4

uni1

uni2

2002

62‐Jun

71

1.27

E+08

10

00

00

2002

62‐Jun

71

7288

304

10

00

00

2002

62‐Jun

71

1566

9730

10

00

00

2002

62‐Jun

71

8649

600

10

00

00

2002

62‐Jun

71

10

00

00

2002

62‐Jun

71

3614

1000

10

00

00

2002

62‐Jun

71

10

00

00

2002

62‐Jun

71

1043

8400

10

00

00

2002

62‐Jun

71

1564

2978

10

00

00

2002

72‐Jul

71

5496

000

10

00

00

2002

72‐Jul

71

9024

000

10

00

00

2002

72‐Jul

71

7082

629

10

00

00

2002

72‐Jul

71

10

00

00

2002

72‐Jul

71

1.26

E+08

10

00

00

2002

72‐Jul

71

7502

807

10

00

00

2002

72‐Jul

71

1608

3919

10

00

00

2002

72‐Jul

71

8678

400

10

00

00

2002

72‐Jul

71

10

00

00

2002

72‐Jul

71

3540

6000

10

00

00

2002

72‐Jul

71

10

00

00

2002

72‐Jul

71

1246

0800

10

00

00

2002

72‐Jul

71

1596

4664

10

00

00

2002

82‐Au

g7

163

3600

01

00

00

020

028

2‐Au

g7

181

6000

01

00

00

020

028

2‐Au

g7

172

2809

41

00

00

020

028

2‐Au

g7

11

00

00

020

028

2‐Au

g7

11.28

E+08

10

00

00

2002

82‐Au

g7

180

2233

71

00

00

020

028

2‐Au

g7

116

2608

471

00

00

020

028

2‐Au

g7

192

2560

01

00

00

020

028

2‐Au

g7

11

00

00

020

028

2‐Au

g7

135

0280

001

00

00

020

028

2‐Au

g7

11

00

00

020

028

2‐Au

g7

111

1616

001

00

00

0


Page 19 of 912

Indiana Michigan Po

wer Com

pany

‐ Indiana

Short‐Term

Large Indu

stria

l Ene

rgy Mod

els Inp

ut Data

year

mon

thacctNO

time

_TYPE_

_FRE

Q_

KWH

hi1

hi2

hi3

hi4

uni1

uni2

2002

82‐Au

g7

116

1981

691

00

00

020

029

2‐Sep

71

6288

000

10

00

00

2002

92‐Sep

71

8424

000

10

00

00

2002

92‐Sep

71

8621

561

10

00

00

2002

92‐Sep

71

10

00

00

2002

92‐Sep

71

1.28

E+08

10

00

00

2002

92‐Sep

71

7486

257

10

00

00

2002

92‐Sep

71

1583

4552

10

00

00

2002

92‐Sep

71

8572

800

10

00

00

2002

92‐Sep

71

10

00

00

2002

92‐Sep

71

3502

8000

10

00

00

2002

92‐Sep

71

10

00

00

2002

92‐Sep

71

1167

3600

10

00

00

2002

92‐Sep

71

1594

4267

10

00

00

2002

102‐Oct

71

5832

000

10

00

00

2002

102‐Oct

71

8136

000

10

00

00

2002

102‐Oct

71

7366

969

10

00

00

2002

102‐Oct

71

10

00

00

2002

102‐Oct

71

1.25

E+08

10

00

00

2002

102‐Oct

71

7082

071

10

00

00

2002

102‐Oct

71

1499

6058

10

00

00

2002

102‐Oct

71

8486

400

10

00

00

2002

102‐Oct

71

10

00

00

2002

102‐Oct

71

3454

5000

10

00

00

2002

102‐Oct

71

10

00

00

2002

102‐Oct

71

1176

0000

10

00

00

2002

102‐Oct

71

1682

2550

10

00

00

2002

112‐Nov

71

6660

000

10

00

00

2002

112‐Nov

71

8544

000

10

00

00

2002

112‐Nov

71

8091

699

10

00

00

2002

112‐Nov

71

10

00

00

2002

112‐Nov

71

1.32

E+08

10

00

00

2002

112‐Nov

71

6693

242

10

00

00

2002

112‐Nov

71

1519

3263

10

00

00


Page 20 of 912

Indiana Michigan Po

wer Com

pany

‐ Indiana

Short‐Term

Large Indu

stria

l Ene

rgy Mod

els Inp

ut Data

year

mon

thacctNO

time

_TYPE_

_FRE

Q_

KWH

hi1

hi2

hi3

hi4

uni1

uni2

2002

112‐Nov

71

8534

400

10

00

00

2002

112‐Nov

71

10

00

00

2002

112‐Nov

71

3259

2000

10

00

00

2002

112‐Nov

71

10

00

00

2002

112‐Nov

71

1175

0400

10

00

00

2002

112‐Nov

71

1609

3055

10

00

00

2002

122‐De

c7

154

0000

01

00

00

020

0212

2‐De

c7

179

2000

01

00

00

020

0212

2‐De

c7

177

8547

21

00

00

020

0212

2‐De

c7

11

00

00

020

0212

2‐De

c7

11.30

E+08

10

00

00

2002

122‐De

c7

162

3000

21

00

00

020

0212

2‐De

c7

114

5825

401

00

00

020

0212

2‐De

c7

110

2144

001

00

00

020

0212

2‐De

c7

11

00

00

020

0212

2‐De

c7

136

3930

001

00

00

020

0212

2‐De

c7

11

00

00

020

0212

2‐De

c7

110

9408

001

00

00

020

0212

2‐De

c7

113

9729

291

00

00

020

031

3‐Jan

71

5724

000

10

00

00

2003

13‐Jan

71

8232

000

10

00

00

2003

13‐Jan

71

6913

516

10

00

00

2003

13‐Jan

71

10

00

00

2003

13‐Jan

71

1.35

E+08

10

00

00

2003

13‐Jan

71

6255

734

10

00

00

2003

13‐Jan

71

1533

7241

10

00

00

2003

13‐Jan

71

9513

600

10

00

00

2003

13‐Jan

71

10

00

00

2003

13‐Jan

71

3312

0837

10

00

00

2003

13‐Jan

71

10

00

00

2003

13‐Jan

71

8428

800

10

00

00

2003

13‐Jan

71

1421

2240

10

00

00

2003

23‐Feb

71

5868

000

10

00

00

2003

23‐Feb

71

7656

000

10

00

00


Page 21 of 912

Indiana Michigan Po

wer Com

pany

‐ Indiana

Short‐Term

Large Indu

stria

l Ene

rgy Mod

els Inp

ut Data

year

mon

thacctNO

time

_TYPE_

_FRE

Q_

KWH

hi1

hi2

hi3

hi4

uni1

uni2

2003

23‐Feb

71

8628

518

10

00

00

2003

23‐Feb

71

10

00

00

2003

23‐Feb

71

1.22

E+08

10

00

00

2003

23‐Feb

71

5937

019

10

00

00

2003

23‐Feb

71

1399

1008

10

00

00

2003

23‐Feb

71

8553

600

10

00

00

2003

23‐Feb

71

10

00

00

2003

23‐Feb

71

3187

8000

10

00

00

2003

23‐Feb

71

10

00

00

2003

23‐Feb

71

1083

5200

10

00

00

2003

23‐Feb

71

1307

5043

10

00

00

2003

33‐Mar

71

5712

000

10

00

10

2003

33‐Mar

71

7728

000

10

00

10

2003

33‐Mar

71

1384

4735

10

00

10

2003

33‐Mar

71

10

00

10

2003

33‐Mar

71

1.22

E+08

10

00

10

2003

33‐Mar

71

6513

242

10

00

10

2003

33‐Mar

71

1478

0797

10

00

10

2003

33‐Mar

71

8361

600

10

00

10

2003

33‐Mar

71

10

00

10

2003

33‐Mar

71

3454

2947

10

00

10

2003

33‐Mar

71

10

00

10

2003

33‐Mar

71

1178

8800

10

00

10

2003

33‐Mar

71

1554

7714

10

00

10

2003

43‐Ap

r7

157

4800

01

00

00

020

034

3‐Ap

r7

184

0000

01

00

00

020

034

3‐Ap

r7

172

2400

01

00

00

020

034

3‐Ap

r7

11

00

00

020

034

3‐Ap

r7

11.22

E+08

10

00

00

2003

43‐Ap

r7

164

9752

11

00

00

020

034

3‐Ap

r7

114

9628

231

00

00

020

034

3‐Ap

r7

191

6800

01

00

00

020

034

3‐Ap

r7

11

00

00

020

034

3‐Ap

r7

129

9505

431

00

00

0


Page 22 of 912

Indiana Michigan Po

wer Com

pany

‐ Indiana

Short‐Term

Large Indu

stria

l Ene

rgy Mod

els Inp

ut Data

year

mon

thacctNO

time

_TYPE_

_FRE

Q_

KWH

hi1

hi2

hi3

hi4

uni1

uni2

2003

43‐Ap

r7

11

00

00

020

034

3‐Ap

r7

111

5200

001

00

00

020

034

3‐Ap

r7

114

1280

151

00

00

020

035

3‐May

71

6420

000

11

00

00

2003

53‐May

71

6960

000

11

00

00

2003

53‐May

71

7656

000

11

00

00

2003

53‐May

71

11

00

00

2003

53‐May

71

1.31

E+08

11

00

00

2003

53‐May

71

6656

785

11

00

00

2003

53‐May

71

1574

2254

11

00

00

2003

53‐May

71

8486

400

11

00

00

Documents

INTEGRATED RESOURCE PLANNING REPORT...• 0.92 per unit to 1.05 per unit in the post-contingency state following the occurrence of any operating condition in categories P1 through