michigan public service commission case no.: u-20068

MICHIGAN PUBLIC SERVICE COMMISSION Case No.: U-20068Consumers Energy Company Exhibit No.: A-1 (JWH-1)

Page: 1 of 1Witness: JWHahn

Date: March 2018

2017 Energy(a) (b) (c) (d)

Line Plan [1] Actual [2] Actual vs PlanNo. Description MWh MWh %1 Steam Coal 11,976,404 10,098,155 -15.68%2 Gas & Oil 5,462,878 5,036,154 -7.81%3 Station Power While Off Line 79,263 - -4 Owned Renewables [6] 1,105,676 1,073,031 -2.95%5 Combustion Turbine (Peaker) 126,627 165,731 30.88%6 Pumped Storage Generation 1,022,700 707,276 -30.84%7 Total Generated 19,773,548 17,080,347 -13.62%8 Pumped Storage Pumping (1,361,157) (997,648) -26.71%9 Total Generated Less Pumping 18,412,391 16,082,699 -12.65%

10 Purchased Power (NUG) [4] [6] 8,366,912 8,305,049 -0.74%11 Nuclear PPA 6,874,194 6,780,140 -1.37%12 Interchange Received [5] 4,226,284 5,726,214 35.49%13 Interchange Delivered (1,949,636) (1,677,543) -13.96%14 Total MWh Requirement 35,930,145 35,216,559 -1.99%

2017 Purchased and Interchange Power Expense/(Revenue)

Line Plan [1] Actual [3] Actual vs PlanNo. Description $*1000 $*1000 %15 Purchased Power (Capacity and Energy) 655,379$ 667,445$ 1.84%16 Nuclear PPA 369,975$ 365,954$ -1.09%17 Interchange Received 124,665$ 186,741$ 49.79%18 Purchase of Zonal Resource Credits 10,761$ 8,964$ -16.69%19 Transmisson Service 409,178$ 352,818$ -13.77%20 Total Received 1,569,958$ 1,581,922$ 0.76%21 Interchange Delivered (77,476)$ (86,790)$ 12.02%22 Schedule 2-Reactive Supply Revenue (5,314)$ (7,375)$ 38.80%23 Total Delivered (82,790)$ (94,166)$ 13.74%

[1] MPSC Case No. U-18142 (Second Supplemental), Exhibit A-39 (STW-4), except lines 19 and 22. Line 19 is from MPSC Case No. U-18142 (Second Supplemental), Exhibit A-27 (DSA-3). Line 22 is from MPSC Case No. U-18142, Direct Testimony of Company witness Daniel S. Alfred.

[2]

For comparison to plan purposes:Line 12 was reduced by the amount shown on Exhibit A-17 (KGT-1), line 10, column (b).Line 13 was increased by the amount shown on Exhibit A-17 (KGT-1), line 10, column (b).

[3] Exhibit A-17 (KGT-1).[4]

[5]

[6]Line 10 includes the subscribed portion of Solar Gardens.

FORECASTED AND ACTUAL GENERATION REQUIREMENTS AND PURCHASED AND INTERCHANGE EXPENSE - 2017

General Accounting Department, Production Summary Report, Period Ending 12/31/17, Except lines 10, 11, 12, & 13, which are from Exhibit A-17 (KGT-1).

Palisades PPA generation removed from actual purchased power and added to line 11 for comparison to plan purposes.Cross Winds generation of 335,504 MWh was removed from actual Interchange Received and added to line 4 for comparison to plan purposes.Line 4 includes the unsubscribed portion of Solar Gardens.

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Case No.: U-20068 Hearing Date: 2-21-2019 Exhibit No.: A-1

MICHIGAN PUBLIC SERVICE COMMISSION Case No.: U-20068Corrected Exhibit No.: A-2 (TEH-1)

Consumers Energy Company Page: 1 of 1Witness: TEHatcher

Date: December 2018

TOTAL 2017(a) (b) (c) (d) (e) (f) (g)

LineEnergy

Delivered Energy Cost Capacity Cost Total CostAverage

Energy Cost Average Total CostNo. Generator (MWh) ($) ($) ($) ($/MWh) ($/MWh)

1 Apple Blossom Wind Farm 34,824 782,205 715,217 1,497,422 22.46 43.002 Blissfield Renewable (Beebe) 186,705 14,517,469 1,978,619 16,496,088 77.76 88.353 Brook View Dairy-AD 4,582 156,205 147,977 304,182 34.09 66.394 Elk Rapids 2 2,267 153,814 47,327 201,140 67.84 88.725 Green Meadow Farms 28 1,852 0 1,852 66.39 66.396 Harvest II Windfarm 174,043 13,512,181 1,752,568 15,264,748 77.64 87.717 Heritage Garden Wind Farm I 57,205 4,168,988 608,871 4,777,859 72.88 83.528 Heritage Stoney Corners I 30,750 1,996,214 337,374 2,333,587 64.92 75.899 Heritage Stoney Corners I (Phase 3) 21,010 1,504,199 227,004 1,731,203 71.60 82.40

10 Michigan Wind 2 260,221 20,185,813 2,513,741 22,699,554 77.57 87.2311 NANR Lennon Generating 11,409 723,315 224,835 948,149 63.40 83.1112 EARP 6,868 378,689 136,667 515,356 55.14 75.0413 Scenic View Dairy-AD 1,915 65,718 61,430 127,148 34.32 66.3914 WM Renewable - Northern Oaks 11,556 598,041 240,972 839,013 51.75 72.6015 WM Renewable Pine Tree Acres 97,718 6,779,714 1,505,704 8,285,418 69.38 84.7916 Solar Gardens-Subscribed 4,960 196,181 160,913 357,094 39.55 71.9917 SUBTOTAL 906,061 65,720,598 10,659,216 76,379,814 72.53 84.3018 Solar Gardens-Unsubscribed-New Build Renewables 1,007 39,819 32,661 72,480 39.55 71.9919 Cross Winds Energy Park - New Build Renewables 335,247 11,359,364 8,420,209 19,779,573 33.88 59.0020 Lake Winds Energy Park - New Build Renewables 257,417 19,864,171 2,670,213 22,534,383 77.17 87.5421 SUBTOTAL - New Build Renewables 593,671 31,263,354 11,123,082 42,386,436 52.66 71.4022 TOTAL 1,499,731 96,983,952 21,782,298 118,766,249 64.67 79.19

PA 295 PURCHASED POWER AND NEW BUILD RENEWABLES

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Case No.: U-20068 Exhibit No.: A-3 (DBK-1)

Page: 1 of 26Witness: DBKehoe Date: March 2018

1

Type Eq Hrs34 688.33

76 230.55

79 4.63

104 20.33

111 221.27

112 1150.88

117 2.27

118 34.72

120 1.12

121 3.27

116 0.53

124 0.53

128 2.07

129 0.20

130 2.52

Eq MWH178966.66

59712.45

1200.03

5286.67

57529.33

299229.67

589.33

9026.33

290.33

849.33

138.67

138.67

537.33

52.00

654.33

Maintenance outage

MO for boiler leak repair

345 kV line fault offsite of JHC, lost 799 OCB

Turbine trip during valve test

Superheat tube failure; finishing SH

PO-critical path:burner replacement; online prior to overspeed (0421 hrs)

Planned & scheduled turbine overspeed (1B turbine)

Exciter PMT; exciter work was original outage scope

Exciter troubleshooting

Turbines on gear & working procedure to perform overspeed test; online 0430

Planned & scheduled turbine overspeed (1A turbine)

Exciter troubleshooting

unit startup, post-overspeed

BCWP differential low; 1D BCWP & BCWP ISWBP - original outage scope

unit startup - ramp; online at 1733, released to ES&T 12/17 @ 0114

DescriptionCause

4460

0770

4460

End

January 2017 to December 2017

3/17/2017 19:12

7/27/2017 16:38

7/31/2017 23:02

10/10/2017 21:44

10/27/2017 6:28

12/14/2017 4:21

12/14/2017 13:24

12/16/2017 0:07

12/16/2017 1:14

12/16/2017 4:30

12/16/2017 12:14

12/16/2017 12:46

12/16/2017 14:50

12/16/2017 15:02

12/16/2017 17:33

Start2/17/2017 1:52

7/18/2017 2:05

7/31/2017 18:24

10/10/2017 1:24

10/18/2017 1:12

10/27/2017 6:28

12/14/2017 11:08

12/14/2017 13:24

12/16/2017 0:07

12/16/2017 1:14

12/16/2017 11:42

12/16/2017 12:14

12/16/2017 12:46

12/16/2017 14:50

12/16/2017 15:02

MO

MO

SF

U1

MO

PO

MO

PO

SF

PO

MO

SF

MO

SF

MO

MICHIGAN PUBLIC SERVICE COMMISSION Consumers Energy Company

Event Summary Report

Report Period:

CAMPBELL 1-2 - CAMPBELL 1

Event0920

1000

3730

9900

1050

0360

4460

4609

4609

4460

4460

4609

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Text Box




2

Type Eq Hrs2 561.33

5 240.72

16 158.92

12 72.00

13 35.90

18 110.45

135 97.30

137 168.32

139 205.25

144 1.93

158 45.48

159 307.82

166 79.93

167 231.02


77 99.52

78 11.08

80 40.98

33860.40

58574.20

71427.00

672.80

16374.00

110814.00

28776.00

83166.00

Eq MWH397347.97

81305.12

9055.08

33483.38

Eq MWH202080.00

86658.00

57210.00

25920.00

12924.00

39762.00

HP Superheat stop valve (2-61-FV-200A) packing failure

2-30-FV-066 rebuild

Outage due to Reheater Tube Leaks.

Outage due to Reheater Tube Leak.

Exciter DC Field Contactors Failed to Make Up, Preventing Syncing.

Drum Blowdown Root Valve Failed PMT.

immediate failure of the turbine lube oil auxiliary oil pump

Turbine lube oil system malfunction

Turbine lube oil system malfunction

cleaning of 77B load center

cleaning of 77B load center

Reliability work for summer run

345 kV line fault offsite of JHC; rupture disc replaced

Work on left RHSV during MO

Ceased startup activities; gen field breaker & SUBFP issues

Required & scheduled turbine overspeed trip testing.

Unit trip during turbine valve testing

SUBFP failure

Description

Description

Cause

Cause

4460

9900

3401

0640

3431

1060

1060

4609

1060

4280

4289

4289

3690

3690

4281

3730

4263

3401

End

End

1/28/2017 0:40

2/13/2017 23:59

2/20/2017 14:54

3/2/2017 0:01

3/3/2017 11:55

3/17/2017 14:30

8/4/2017 20:17

8/11/2017 20:36

8/23/2017 15:30

8/29/2017 11:42

9/20/2017 22:46

10/3/2017 18:35

5/5/2017 3:31

5/6/2017 7:11

10/17/2017 11:45

10/27/2017 2:46

5/1/2017 0:00

5/5/2017 3:31

5/5/2017 14:36

5/8/2017 0:10

Start1/4/2017 15:20

2/3/2017 23:16

2/13/2017 23:59

2/27/2017 0:01

3/2/2017 0:01

3/13/2017 0:03

7/31/2017 18:59

8/4/2017 20:17

8/15/2017 2:15

8/29/2017 9:46

9/19/2017 1:17

9/20/2017 22:46

MO

MO

MO

10/14/2017 3:49

SF

CAMPBELL 1-2 - CAMPBELL 2

Event

CAMPBELL 3 - CAMPBELL 3

Event

ME

MO

ME

MO

U1

MO

SF

MO

U1

SF

U1

MO

MO

ME

10/17/2017 11:45

Start4/10/2017 17:39

5/1/2017 0:00



3

Type Eq Hrs2 4.33

4 145.07

6 32.92

8 4.32

10 26.05

13 0.23

Type Eq Hrs2 1.65

3 21.42

10 1367.73

12 0.85

51.80

312.60

2.80

Eq MWH18.15

235.58

14646.92

8.50

Eq MWH73.67

1740.80

395.00

ITC Switching in the substation

Breaker repairs

ITC Work - Spared 148 OCB

RTU Maintenance Switch found in the wrong position

Relay Testing

Trouble Shooting SCADA issue

Failed to auto synchronize

Fix auto synchronize

Broken Exhaust Duct Flange

Unit Failed to sync

Description

Description

Cause

Cause

3610

4810

3700

9900

3644

5248

4720

4720

5109

4720

End

End

9/21/2017 14:25

11/21/2017 14:12

11/17/2017 13:09

11/21/2017 15:03

Start5/26/2017 17:13

6/6/2017 10:56

7/11/2017 7:05

7/20/2017 8:52

7/24/2017 10:33

7/27/2017 14:53

Start1/12/2017 11:15

1/12/2017 13:03

5/26/2017 21:33

6/12/2017 12:00

7/12/2017 16:00

7/20/2017 13:11

7/25/2017 12:36

7/27/2017 15:07

1/12/2017 12:54

1/13/2017 10:28

U1

CE PEAKERS - STRAITS 1

Event

MO

MO

SF

MO

MO

SF

U1

SF

SF

CE PEAKERS - CAMPBELL PEAKER

Event



4

Type Eq Hrs5 0.45

7 101.87

9 201.00

10 21.33

11 22.22

12 0.50

13 1.27

17 19.45

21 1.58

23 5.32

28 5.10

32 0.40

34 175.35

35 1.45

36 0.23

38 7.18

Type Eq Hrs4 1.95

6 101.87

10 168.52

11 1.42

12 26.60

13 0.60

14 0.40

16 19.45

20 1.58

28 2.00

30 47.32

25.33

32.00

742.23

22.17

74.43

71.40

5.60

2454.90

20.30

3.27

107.75

Eq MWH31.20

1629.87

2696.27

22.67

425.60

9.60

6.40

311.20

Eq MWH6.30

1426.13

2814.00

298.67

311.03

7.00

17.73

272.30

Fuel Control Upgrades

Test Run Complete - Fuel Control Upgrades




Fire Trip while testing Gaylord 3

SubStation Testing

Testing


ITC 138KV bus inspection


Completed Test Run - Fuel Control Upgrades




Fire Trip while testing Gaylord Unit #3

SubStation Outage

DC Ground Indication Trouble Shooting

Ratchet Motor Failure - Replaced Motor

Unit Tripped on High Exhaust Temperature




Software Update

Failed to start due to failure to fire


Replace turning gear timer

Description

Description

Cause

Cause

4899

3700

5048

5048

5048

5048

5048

5299

3700

3659

5450

5108

5048

5048

5048

5249

5050

3700

5048

5048

5048

5048

5048

5299

3700

5048

5048

End

End

10/30/2017 15:03

10/30/2017 15:31

11/2/2017 15:22

1/9/2017 9:49

2/17/2017 13:27

5/10/2017 9:32

5/10/2017 11:02

5/11/2017 13:49

5/11/2017 15:11

5/11/2017 15:48

5/17/2017 7:57

9/6/2017 11:49

10/30/2017 9:00

11/1/2017 14:50

10/30/2017 15:17

11/2/2017 8:11

Start1/9/2017 7:52

2/13/2017 7:35

5/3/2017 9:01

5/10/2017 9:37

5/10/2017 11:13

5/11/2017 14:35

5/11/2017 15:24

5/16/2017 12:30

9/6/2017 10:14

10/30/2017 7:00

10/30/2017 15:31

Start1/11/2017 13:08

2/13/2017 7:35

4/24/2017 7:05

5/2/2017 16:30

5/3/2017 14:54

5/4/2017 13:49

5/4/2017 14:29

5/16/2017 12:30

9/6/2017 10:14

9/11/2017 9:11

9/23/2017 11:19

9/26/2017 14:00

10/23/2017 6:00

10/30/2017 13:36

1/11/2017 13:35

2/17/2017 13:27

5/2/2017 16:05

5/3/2017 13:50

5/4/2017 13:07

5/4/2017 14:19

5/4/2017 15:45

5/17/2017 7:57

9/6/2017 11:49

9/11/2017 14:30

9/23/2017 16:25

9/26/2017 14:24

10/30/2017 13:21

MO

MO

U1

MO

MO

MO

MO

MO

MO

MO

GAYLORD - GAYLORD 1

Event

GAYLORD - GAYLORD 2

Event

MO

U1

U1

U1

MO

MO

MO

U1

SF

MO

U1

MO

MO

MO

MO

MO

MO



5

Type Eq Hrs3 101.87

5 95.30

6 0.95

7 18.25

8 1.98

9 2.17

10 23.53

11 21.98

12 0.50

13 0.30

16 22.83

19 1.58

29 49.73

30 0.22

31 0.42

32 0.17

3.03

5.83

2.33

Eq MWH1426.13

1334.20

13.30

255.50

27.77

30.33

329.47

307.77

7.00

4.20

251.17

22.17

696.27



Hydraulic Servo failure

SubStation Testing


Fuel Control Upgrades - Test run complete











DescriptionCause3700

5048

5048

5048

5048

5048

5048

5048

5048

5048

5120

3700

5048

5048

5048

5048

End2/17/2017 13:27

5/15/2017 14:47

5/15/2017 16:025/15/2017 15:05

5/15/2017 16:19

5/16/2017 10:45

5/16/2017 13:01

5/16/2017 15:31

5/17/2017 15:17

5/18/2017 13:39

5/18/2017 14:23

7/26/2017 16:10

9/6/2017 10:14

11/1/2017 13:44

11/3/2017 15:53

11/3/2017 16:17

11/3/2017 16:51

5/16/2017 10:34

5/16/2017 12:44

5/16/2017 15:11

5/17/2017 15:03

5/18/2017 13:16

5/18/2017 14:09

5/18/2017 14:41

7/27/2017 15:00

9/6/2017 11:49

11/3/2017 15:28

11/3/2017 16:06

11/3/2017 16:42

11/3/2017 17:01

Start2/13/2017 7:35

5/11/2017 15:29

MO

MO

MO

MO

MO

MO

MO

MO

MO

MO

U1

MO

MO

MO

MO

MO

GAYLORD - GAYLORD 3

Event



6

Type Eq Hrs1 168.03

3 5.50

5 3.50

6 4.00

Type Eq Hrs1 385.33

2 100.70

3 5.00

4 1.88

Type Eq Hrs1 1.25

2 4.00

3 210.93

4 5122.93 1236.86

Eq MWH226.85

7.98

5.08

5.80

Eq MWH558.73

135.95

7.25

2.73

Eq MWH0.31

1.00

52.73

Undervoltage trip, high winds

Distribution overvoltage, broken wicket gate

Noise - Lower Guide Bearing Issue

HCMS Installation Outage

Dive Inspection

Tailrace Dive Inspection

Dirty GLS-X Relay Contact

Periodic Outage


Dive Inspection


46 KV line trip at Williams sub

Description

Description

Description

Cause

Cause

Cause

7201

7201

3644

7201

3950

7201

7201

3644

3644

3644

3644

3950

End

End

End

11/27/2017 9:30

12/23/2017 7:00

Start2/6/2017 10:30

6/19/2017 11:00

9/27/2017 8:53

11/27/2017 13:00

Start1/10/2017 18:10

3/8/2017 14:35

5/2/2017 18:34

6/1/2017 14:04

11/27/2017 13:00

12/23/2017 11:00

2/22/2017 11:50

6/23/2017 15:42

9/27/2017 13:53

11/27/2017 14:53

1/10/2017 19:25

3/8/2017 18:35

5/11/2017 13:30

1/1/2018 0:00

Start6/12/2017 10:13

10/2/2017 9:00

6/19/2017 10:15

10/2/2017 14:30

PO

MO

U1

U1

U1

U1

PO

PO

MO

U1

PO

PO

Event

HYDROS - ALLEGAN 1

Event

HYDROS - ALCONA 1

Event

HYDROS - ALCONA 2



7

Type Eq Hrs1 1.17

2 0.63

3 4.00

4 1.52

5 288.00

6 17.33

7 3.98

9 3.83

8 48.50

Type Eq Hrs1 1.08

2 0.58

3 4.00

4 1.60

5 95.02

6 49.00

7 3.98

9 4.18

8 0.50

Type Eq Hrs1 0.58

2 2.67

3 240.00

4 52.75

29.40

3.07

3.22

0.39

Eq MWH0.88

4.00

360.00

79.13

Eq MWH0.68

0.37

2.32

0.88

135.36

8.15

2.31

2.22

28.13

Eq MWH0.83

0.45

3.08

1.23

57.01

Broken Limit Switch Bracket

Clean Trash Rack & Spill Leaves


27/59 & 50 relay due to fault

Bus PT switches opened

Sealing Unit 2 Headgate leaks




Voltage trip, testing at Williams Sub


Distribution Overvoltage

Periodic Outage

Planned Outage Extension



Headgate Replacement


Voltage trip, testing at Williams Sub


Distribution Overvoltage

Dive Inspection

Description

Description

Description

Cause

Cause

Cause

7110

7110

7120

3644

3644

3644

3644

7201

3644

7110

7110

3644

3644

7120

3950

3950

3644

3644

3644

3644

7201

7201

End

End

End

4/5/2017 9:55

9/11/2017 9:30

9/21/2017 9:30

4/5/2017 12:35

9/21/2017 9:30

9/23/2017 14:15

6/14/2017 14:40

6/26/2017 14:40

11/29/2017 7:03

12/2/2017 7:10

12/14/2017 13:15

Start1/10/2017 18:10

2/21/2017 12:09

3/8/2017 14:35

5/2/2017 18:34

7/17/2017 10:59

8/3/2017 10:00

11/29/2017 7:03

12/2/2017 7:49

12/15/2017 11:08

Start3/20/2017 12:00

6/26/2017 14:40

6/27/2017 8:00

11/29/2017 11:02

12/2/2017 11:00

12/16/2017 13:45

1/10/2017 19:15

2/21/2017 12:44

3/8/2017 18:35

5/2/2017 20:10

7/21/2017 10:00

8/5/2017 11:00

11/29/2017 11:02

12/2/2017 12:00

12/15/2017 11:38

3/20/2017 12:35

Start1/10/2017 18:10

2/21/2017 12:09

3/8/2017 14:35

5/2/2017 18:34

1/10/2017 19:20

2/21/2017 12:47

3/8/2017 18:35

5/2/2017 20:05

U3

MO

U1

U1

U2

PO

PE

U1

U1

U1

U1

PO

PE

U3

MO

PO

U1

U1

U1

U1

HYDROS - ALLEGAN 2

Event

HYDROS - ALLEGAN 3

Event

HYDROS - COOKE 1

Event

HYDROS - COOKE 2

PO

U1



8

Type Eq Hrs1 1.67

2 0.58

4 216.00

5 3.00

3 42.45

6 49.22

7 2.50

8 73.47

9 240.00

10 96.05

Type Eq Hrs1 268.02

2 240.00

3 52.75

4 24.92

5 96.92

6 219.87


2 427.20

3 193.15

4 735.17

Type Eq Hrs1 2.85

198.36

648.00

259.34

Eq MWH750.45

672.00

147.70

69.77

271.37

615.63

Eq MWH1844.31

726.24

328.36

1249.78

Eq MWH4.85

Eq MWH4.50

1.58

583.20

8.10

114.62

132.89

6.75


Periodic outage



Planned Inspection Outage.

Planned Inspection Outage

Blown DC control fuse

Bus PT switches opened

Periodic Outage

Periodic Outage Extension

Blown fuse in AVR

Unit #2 AVR failed to excite the generator

Unit #2 AVR failed to excite the generator

Ongoing AVR issue


DescriptionCause

Cause

Cause

Cause

3644

7201

7201

3644

3644

3644

3644

3950

3950

7201

3950

3950

7201

7201

7201

3644

3644

3644

7007

3644

Description

Description

Description

Planned Inspection Outage Extension

Electrical upgrade.

Electrical Upgrade Extended

Had to locate grounds between powerhouse and switchyard.

Noise from Turbine Bearing

Low governor oil pressure

3644

End

End

End

End

9/21/2017 9:30

10/23/2017 9:20

11/2/2017 10:20

11/6/2017 10:15

Start7/10/2017 8:18

9/9/2017 18:18

10/2/2017 13:21

12/1/2017 8:50

Start1/26/2017 20:39

1/1/2018 0:00

1/26/2017 23:30

Start3/16/2017 9:25

3/20/2017 12:00

4/3/2017 8:30

4/12/2017 8:30

4/15/2017 16:46

7/22/2017 11:17

7/25/2017 11:15

8/7/2017 10:42

9/11/2017 9:30

9/21/2017 9:30

Start3/20/2017 9:33

9/11/2017 9:30

3/16/2017 11:05

3/20/2017 12:35

4/12/2017 8:30

4/12/2017 11:30

4/17/2017 11:13

7/24/2017 12:30

7/25/2017 13:45

8/10/2017 12:10

9/21/2017 9:30

9/25/2017 9:33

3/31/2017 13:34

9/21/2017 9:30

U1

U1

U1

U1

PO

PE

U1

U1

U1

U1

9/23/2017 14:15

10/24/2017 10:15

11/6/2017 10:15

11/15/2017 14:07

9/9/2017 8:18

9/27/2017 13:30

10/10/2017 14:30

U1

U1

PO

PE

HYDROS - COOKE 3

Event

HYDROS - CROTON 1

Event

HYDROS - CROTON 2

Event

PO

PO

PE

PO

PO

PE

PO

Event



9

2 3.38

3 233.03

4 1464.00

5 1203.40

Type Eq Hrs1 43.65

2 1.17

3 4285.35

Type Eq Hrs1 0.08

2 3.13

3 0.17

4 0.75

5 71.37

6 0.50

7 192.43

8 4329.98

Type Eq Hrs1 1.92

2 455.22

3 10.03

4 263.17

5 223.18

Eq MWH6.13

1456.69

32.11

842.13

714.19

5.75

396.16

1823.05

2045.78

Eq MWH32.74

0.88

3010.56

Eq MWH0.06

2.35

0.13

0.56

53.53

0.38

142.79

3065.36

Planned Outage/Periodic Outage/Electrical Test

Cause

Cause

Cause

Brush rigging failure

Guide bearing oil pressure trip

Losing Bearing Oil

Water in thrust/pedestal bearing oil


Activation of DRX relay by the AVR

Due to Loud U1 PO, Five Channels is off for disparity reasons.

7201


Governor leaks, tripped

3644

3644

3644

3644

3644

3644

3644

3644

3644

3644

3644

3644

3644

7009

3950

3644

7201

Description

Description

Description

Electrical upgrade.

Electrical Outage Extended


HCMS Trip

Unit swing due to Unit #4 issue.

Faulty trip circuit

Low Governor Oil Pressure

Low Governor Oil Pressure

Faulty trip circuit

Guide Bearing Oil Temperature Trip

3644

3644

End

End

End

4/6/2017 10:38

7/6/2017 11:39

Start1/6/2017 12:54

1/20/2017 11:10

1/20/2017 14:39

2/19/2017 5:30

4/2/2017 13:47

5/24/2017 8:45

5/24/2017 11:25

7/4/2017 15:01

Start7/25/2017 13:00

10/9/2017 9:04

11/14/2017 0:13

11/27/2017 9:30

12/11/2017 5:59

4/6/2017 11:48

1/1/2018 0:00

1/6/2017 12:59

1/20/2017 14:18

1/20/2017 14:49

2/19/2017 6:15

4/5/2017 13:09

5/24/2017 9:15

6/1/2017 11:51

1/1/2018 0:00

7/25/2017 14:55

10/28/2017 8:17

11/14/2017 10:15

12/8/2017 8:40

12/20/2017 13:10

2/19/2017 2:52

2/20/2017 17:00

7/8/2017 14:36

9/7/2017 14:36

Start2/20/2017 13:52

2/19/2017 6:15

3/2/2017 10:02

9/7/2017 14:36

10/27/2017 18:00

2/22/2017 9:31

U1

PO

U1

MO

PO

HYDROS - FIVE CHANNELS 2

U1

U1

U1

U1

U1

U1

U1

U1

U1

U1

U1

HYDROS - CROTON 4

Event

HYDROS - CROTON 3

Event

HYDROS - FIVE CHANNELS 1

Event

U1

U1

PO

PE



10

Type Eq Hrs1 455.22

Type Eq Hrs1 1.17

2 223.40

3 19.27


2 963.10

Type Eq Hrs1 0.50

2 223.40

Type Eq Hrs3 271.62

6 5.43

Type Eq Hrs1 262.72

6 267.80

8 76.25

9 5.77

239.04

Eq MWH2716.17

54.33

Eq MWH2627.17

2892.24

823.50

57.67

Eq MWH1365.65

Eq MWH1.24

236.80

20.42

Eq MWH7425.11

1030.52

Eq MWH0.52


Faulty Panalarm trip device


7201

3644

4630

7201

Cause

Cause

Cause

Cause

Cause

Cause

Description

Description

Description

Exciter won't excite the unit

Lower steady bearing wear

Field Switch Forced Outage

316 Breaker Tripper by Contractor (HCMS)


Periodic Outage

Tailrace Inspection

Periodic Outage

Description

Description

3950

3644

3950

4609

7007

3644

3644

3950

7201

7201

Unit #3 spill tube re-lining/diver

End

End

End

End

End

End

10/28/2017 8:17

1/11/2017 16:14

10/6/2017 16:45

12/27/2017 11:00

10/20/2017 14:54

11/29/2017 17:00

7/18/2017 14:32

10/6/2017 16:45

3/24/2017 15:37

9/21/2017 13:36

2/25/2017 10:30

8/4/2017 13:50

8/11/2017 14:45

9/21/2017 13:56

Start1/1/2017 0:00

10/20/2017 14:54

Start7/18/2017 14:02

9/27/2017 9:21

Start3/13/2017 8:00

9/21/2017 8:10

Start2/14/2017 11:47

7/24/2017 10:02

8/8/2017 10:30

9/21/2017 8:10

Description

Issue with cooling water discharge piping.

Tailrace Inspection

PO

PO

PO

PO

Event

HYDROS - FOOTE 1

Event

HYDROS - FOOTE 2

Start

EventPO

PO

MO

PO

Event

HYDROS - FOOTE 3

Event

HYDROS - HARDY 1

Event

HYDROS - HARDY 2

U1

PO

U1

U1

U1

U1

10/9/2017 9:04

Start1/11/2017 15:04

9/27/2017 9:21

12/26/2017 15:44



11

10 10.37

Type Eq Hrs4 7.30

5 1800.00

6 1197.00

7 49.17

Type Eq Hrs1 123.23

3 1.33

4 2.25

2 837.92

5 43.95

2.67

4.50

1675.83

98.89

103.67

Eq MWH83.95

20700.00

13765.50

565.42

Eq MWH277.28

3644

7053

Description

Description

Cause

7102

7201

Cause

3644

4630

3644

7201

7201

End

End

11/16/2017 17:22

7/10/2017 14:00

10/1/2017 12:15

11/16/2017 7:00

7/18/2017 12:15

10/1/2017 12:15

11/20/2017 12:50

Start2/24/2017 8:21

6/20/2017 12:58

6/21/2017 8:49

7/26/2017 15:00

11/20/2017 15:00

11/20/2017 8:15

11/22/2017 14:00

3/1/2017 11:35

6/20/2017 14:18

6/21/2017 11:04

8/30/2017 12:55

11/22/2017 10:57

3644

Start7/10/2017 6:42

Remove Unit #3 Coffer Dam

Dive inspection.

Spill tube re-lining

Spill tube re-lining outage extended.

Plugged Cooling Water Line

Breaker failed to close

Dive Inspection

Dive Inspection

Seal oil leak

Governor Oil Pump Leak

PO

U1

MO

MO

PO

PO

PE

HYDROS - HARDY 3

Event

HYDROS - HODENPYL 1

Event

MO

U1

PO



12

Type Eq Hrs1 1.57

2 2.58

3 46.63

Type Eq Hrs1 455.28

2 263.17

3 4.00

Type Eq Hrs1 455.28

Type Eq Hrs1 456.00

2 142.38

3 224.75

4 4729.87

161.33

3603.81

Eq MWH3.13

5.17

104.93

Eq MWH1001.62

578.97

8.80

Eq MWH1001.62

Eq MWH364.80

113.91

7201

7201

7053

Cause

Description

Description

Description

Description


End

End

Dive Inspection

Dive Inspection



Planned Thrust Inspection Outage

3950

7201

3644

3950

7201

7201

3950

Cause

Cause

Cause

High Steady Bearing Temperature Trip3644

Dirty GLS-X Relay Contact


Periodic Outage

Periodic Outage

End

Start10/9/2017 9:00

Start1/9/2017 14:37

1/28/2017 14:37

5/30/2017 8:00

6/17/2017 23:08

10/28/2017 8:17

1/28/2017 14:37

2/3/2017 13:00

6/8/2017 16:45

1/1/2018 0:00

Start6/20/2017 9:46

6/21/2017 12:09

12/27/2017 12:22

Start10/9/2017 9:00

11/27/2017 9:30

12/23/2017 7:00

6/20/2017 11:20

6/21/2017 14:44

12/29/2017 11:00

10/28/2017 8:17

12/8/2017 8:40

12/23/2017 11:00

End

PO

U1

PO

PO

U1

PO

PO

PE

PO

U1

PO

HYDROS - MIO 1

Event

HYDROS - HODENPYL 2

Event

HYDROS - LOUD 1

Event

HYDROS - LOUD 2

Event



13

Type Eq Hrs1 240.00

2 7.42

3 1.85

4 24.50

5 2.03

6 3.25

7 3.17

8 3.53


2 199.08

3 2.87


2 103.25 82.60

Eq MWH172.00

5.19

1.30

17.15

1.42

2.60

2.53

2.83

Eq MWH5206.39

159.27

2.29

Eq MWH5206.39

Description

11/14/2017 10:30

11/28/2017 14:10

10/16/2017 10:59

1/1/2018 0:00

Description

High ITC Transmission Line Voltage

Station Power Transformer Outage

Trash Rack Dive Inspection

HCMS Installation Outage3950

3950

9940

7201

3644

3622

7201

7201

3644

3644

7050

7007

7053

Cause

Cause

Cause

Description


Failed thrust bearing

Unit #1 Field Failure

Install Gate Operator Battery Inverter

Failed thrust bearing

Mis-match on #2 Governor System/Possible oil leak.


199 Breaker tripped by Substation Tech.

Trash rack maintenance outage/aux oil pump issue

10/16/2017 10:59

End

End

End

Start5/30/2017 8:00

6/9/2017 8:00

7/12/2017 8:49

7/24/2017 9:30

8/22/2017 19:28

10/30/2017 10:00

11/7/2017 11:20

11/29/2017 9:32

Start

6/9/2017 8:00

6/9/2017 15:25

7/12/2017 10:40

7/25/2017 10:00

8/22/2017 21:30

10/30/2017 13:15

11/7/2017 14:30

11/29/2017 13:04

PE

U1

U3

U1

MO

MO

MO

U1

U1

PO

HYDROS - MIO 2

Event

HYDROS - ROGERS 1

Event

HYDROS - ROGERS 2

Event

MO

U1

U1

1/1/2017 0:00

11/6/2017 3:25

11/28/2017 11:18

Start1/1/2017 0:00

12/27/2017 16:45



14


Type Eq Hrs1 239.25

2 339.43

Type Eq Hrs1 7.45

2 267.78

Type Eq Hrs1 7.43

2 267.75

Type Eq Hrs1 4.83

2 271.68

Eq MWH4327.20

Eq MWH155.51

271.55

Eq MWH15.42

589.12

Eq MWH15.39

589.05

Eq MWH9.96

597.70

Description

Description

DC (Exciter) Ground Detector Fault

Dive Inspection

Periodic Inspection Outage

End

1/1/2018 0:00

6/25/2017 13:00

10/14/2017 15:11

8/1/2017 17:29

9/22/2017 17:21

HYDROS - ROGERS 3

Event

HYDROS - ROGERS 4

7141

3644

3644

Cause

Cause

Dive Inspection

Periodic Inspection Outage

Dive Inspection

Wicket gate binding

Swan dove into substation.

End

End

7201

7201

7201

7201

7201

7201

8/1/2017 17:30

10/6/2017 16:13

8/2/2017 13:39

10/20/2017 16:30

Start6/15/2017 13:45

9/30/2017 11:45

Start8/1/2017 10:02

9/11/2017 13:34

Start8/1/2017 10:04

9/25/2017 12:28

Start8/2/2017 8:49

10/9/2017 8:49

End

End

U1

U1

PO

PO

PO

PO

PO

PO

Event

HYDROS - TIPPY 1

Event

HYDROS - TIPPY 2

Event

HYDROS - TIPPY 3

Event

Cause

Cause

Cause

Description

Description

Description

Planned Maintenance Outage

U2

Start5/3/2017 10:00



15

Type Eq Hrs1 336.00

2 2.45

3 29.93

Type Eq Hrs1 469.70

2 336.00

Type Eq Hrs5 13.10

51 181.42

53 2.63

54 18.73

55 10.95

171 13.07

177 3.78

218 12.67

239 120.00

240 10.80

248 1.68

252 0.97 523.93

3.43

41.91

Eq MWH187.88

134.40

Eq MWH7100.20

98327.84

1427.27

10153.47

5934.90

7082.13

2050.57

6865.33

65040.00

5853.60

912.37

Eq MWH470.40

"C" boiler feed pump exchange

"C" Boiler Feed pump exchange

Loss of south 138KV bus due to LM#2 52G breaker failure

Description

9130

9130

3659

3643

3410

3410

3410

4810

Cause

Annual Smolt Spill

Rheostat problem.

Rheostat problem.

Main cable damage

Annual Smolt Spill

Clean and inspect main DC bus and ground isolation

Unit annual siwtchyard maint

Unit annual switchyard outage

unit annual switchyard outage

Gas supplier ,Vector , secured gas supply to the plant due to a emergency event

Enbridge replaced valve actuator at Vector Leslie gas yard

LM#1 generating breaker charging motor failure causing short term DC bus short circuit

Plant UPS inverter automatic bypass due to over heating caused by failed cooling fans

Feed pump exchange

End

End

9590

3644

3644

3619

9590

3659

3619

3619

3619

5/29/2017 8:00

10/13/2017 9:52

10/16/2017 14:50

Start5/15/2017 8:00

10/13/2017 7:25

10/15/2017 8:54

End

Start1/12/2017 0:14

4/22/2017 1:01

4/29/2017 16:57

4/29/2017 22:10

5/5/2017 10:10

10/17/2017 5:00

10/22/2017 7:37

11/13/2017 23:13

12/10/2017 0:16

12/15/2017 0:16

12/15/2017 11:08

12/26/2017 4:10

1/12/2017 13:20

4/29/2017 14:26

4/29/2017 19:35

4/30/2017 16:54

5/5/2017 21:07

10/17/2017 18:04

10/22/2017 11:24

11/14/2017 11:53

12/15/2017 0:16

12/15/2017 11:04

12/15/2017 12:49

12/26/2017 5:08

StartU1

PO

MO

PO

PO

PO

U1

PO

PE

PO

U1

PO

U1

U1

HYDROS - WEBBER 1

U1

MO

U1

JACKSON GENERATING STATION - JACKSON GENERATING STATION

1/1/2017 0:00

5/15/2017 8:00

1/20/2017 13:42

Event

Event

HYDROS - WEBBER 2

Event

5/29/2017 8:00

Cause

Cause

Description

Description



16

Type Eq Hrs1 43.95

2 98.35

23 350.35

25 322.73

61 10.22

76 4.70

77 5.45

78 1.28

79 0.72

80 3.60

131 419.18

136 2.42

141 6.58

142 12.08

158 111.13

159 84.70


196 24.75

197 437.00

214 66.98

216 7.97

217 32.97

239 1594.90

241 234.02

244 0.67

21598.50

Eq MWH118941.33

6435.00

113620.00

17415.67

2071.33

8571.33

414674.00

60844.33

173.33

Eq MWH11207.25

25079.25

89339.25

82297.00

2605.25

1198.50

1389.75

327.25

182.75

918.00

106891.75

616.25

1678.75

3081.25

28339.00

DI water shortage

Screen Drive Outage

Hydrogen leak repairs on turbine

SF due to 299 metering knife switches not closed

Unit Trip during Valve Test

EHC Leak

Grounds on 1B 480 Bus

MO for EHC Leak

SF for field reostat

MO for EHC leak

Karn 1 MO for boiler damper repair

Stop the job on BCWP

Karn 1 MO for boiler damper repair

Maint extension

MO for boiler leak

MO for boiler leak

Maintenance Outage for Boiler Leak

Boiler leak

Outage for boiler leaks

Boiler Leak extension

start up failure for scaffold boards in boiler

repair reheat gas distribution damper - continuation of event 0110

oil leak on HPU system

superheater leak

repair south throttle valve

Description

Description

Cause

Cause

4293

1599

3210

1599

1599

1090

1090

1000

1005

1005

1005

9910

3300

3260

4613

9930

4267

4293

4860

4293

4601

1520

End

End

4293

1040

4260

9/19/2017 5:00

9/21/2017 23:59

9/22/2017 7:57

9/23/2017 16:55

12/17/2017 9:00

12/29/2017 11:29

12/29/2017 12:09

3/7/2017 16:44

6/2/2017 17:51

7/17/2017 6:51

7/17/2017 11:33

7/17/2017 17:00

7/17/2017 18:17

7/17/2017 19:00

10/6/2017 21:19

10/24/2017 8:30

10/24/2017 10:55

10/24/2017 17:30

11/26/2017 8:52

12/1/2017 0:00

Start2/10/2017 0:05

8/30/2017 23:15

9/1/2017 0:00

3/21/2017 4:28

6/3/2017 4:04

7/17/2017 11:33

7/17/2017 17:00

7/17/2017 18:17

7/17/2017 19:00

7/17/2017 22:36

10/24/2017 8:30

10/24/2017 10:55

10/24/2017 17:30

10/25/2017 5:35

12/1/2017 0:00

12/4/2017 12:42

3/1/2017 1:33

9/1/2017 0:00

Start1/1/2017 0:00

1/2/2017 19:57

2/21/2017 2:23

1/2/2017 19:57

1/6/2017 22:18

3/7/2017 16:44

MO

ME

SF

MO

PO

MO

SF

9/19/2017 5:00

9/21/2017 23:59

9/22/2017 7:57

10/11/2017 23:06

12/19/2017 17:28

12/29/2017 11:29

MO

SF

MO

MO

SF

MO

ME

MO

MO

MO

MO

KARN 1-2 - KARN 2

Event

MO

SF

MO

PO

MO

MO

SF

KARN 1-2 - KARN 1

Event



17


2 141.05

3 177.77

4 485.42

7 184.02

10 101.38

11 1.88

12 154.68

14 2.12

13 109.45

15 3.42

16 10.90

17 1.48

18 61.10

19 2.63

20 16.32

24 1.42

25 1.78

32 11.87

34 7.82

37 1.73

38 3.53

40 0.20

44 2.05

45 0.57

48 1.25

49 6.15

51 3.60

52 6.18

53 3.95

55 2.02

58 957.72

63 249.67

121.60

1246.40

344.53

760.00

3739.20

2188.80

3759.47

2401.60

1226.13

582291.73

151797.34

61438.30

1141.30

93738.10

1282.70

65707.80

2050.00

6540.00

890.00

36660.00

1580.00

9790.00

850.00

1070.00

7120.00

4690.00

1053.87

2148.27

Eq MWH1402051.70

85476.31

107726.59

294162.50

111514.09

Boiler Trip

Plant house heating outage

Ongoing reported issues with AVR

Periodic Outage Continuation



generator LOR

3BID Fan air control valve

899 electrical relay failure

Turbine valve closed computer card failure

Valve testing failure

valve testing failure

Fan issues to be determined

Intercept Valve Closed (Control Issue)

Boiler Level High Trip- Feedwater Manual Control

Intercept Valve Closing

Valve Control Issue - Intermittent Stop

Turbine Valve Control (Closing)

Control Valve Closed - Control Issue

Control Valve Closing (Control Issue)

Breeching replacement and repair, 3B ID fan repair. BOP work.




Peroidic Outage continuation

Periodic Outage continuation

periodic outage continuation

periodic outage continuation



Planned Outage Continuation

Planned Outage Continuation


DescriptionCause

9320

4262

4309

4309

1400

4260

1999

4260

4260

4260

4260

4260

1420

3999

4899

1510

1510

1510

1510

1510

1510

1510

1510

1510

1510

1510

1510

1510

1510

1510

4899

3899

1510

End

6/5/2017 14:01

6/6/2017 3:08

6/6/2017 6:33

6/9/2017 4:20

6/9/2017 11:44

6/10/2017 4:57

6/12/2017 3:31

7/19/2017 12:43

8/20/2017 18:36

8/22/2017 11:33

9/12/2017 12:13

9/12/2017 16:36

9/13/2017 13:27

9/21/2017 13:28

9/21/2017 14:07

9/24/2017 5:17

9/24/2017 11:31

4/7/2017 10:37

4/13/2017 9:25

4/21/2017 0:00

5/11/2017 5:25

5/19/2017 13:20

5/23/2017 22:19

5/24/2017 6:58

5/31/2017 7:04

5/31/2017 13:17

6/5/2017 7:09

9/13/2017 13:15

9/21/2017 11:25

9/21/2017 13:33

9/24/2017 4:02

9/24/2017 5:22

9/24/2017 18:34

9/25/2017 7:43

9/25/2017 16:14

9/26/2017 15:26

10/9/2017 0:00

12/12/2017 5:18

9/24/2017 22:10

9/25/2017 13:54

9/25/2017 20:11

9/26/2017 17:27

11/17/2017 20:43

12/22/2017 14:58

5/19/2017 16:56

5/24/2017 5:05

5/24/2017 20:23

5/31/2017 11:10

5/31/2017 17:42

6/5/2017 10:36

6/5/2017 16:14

6/6/2017 5:04

6/6/2017 15:14

6/9/2017 9:06

6/9/2017 12:38

6/12/2017 2:06

7/19/2017 10:56

8/20/2017 6:44

8/22/2017 3:44

9/12/2017 10:29

9/12/2017 13:04

U1

U1

U1

U1

MO

MO

PO

PO

PO

PO

PO

PO

SF

U1

SF

U1

MO

MO

SF

SF

U1

U1

U1

PO

PO

PO

PE

PO

PO

PO

PO

PO

PO

KARN 3-4 - KARN 3

Event Start1/1/2017 0:00

4/7/2017 12:22

4/13/2017 14:14

4/21/2017 0:00

5/11/2017 21:19



18

66 95.75


2 90.38

3 259.70

4 187.42

5 295.57

6 448.28

15 21.95

17 25.65

16 144.82

9 3.30

18 44.35

13 2.97

11 12.50

27 3.30

20 7.58

30 0.97

24 47.97

26 9.25

32 16.58

33 0.85

34 3.67

38 12.47

40 11.87

47 2.95

48 4.35

52 2209.00

Type Eq Hrs2 775.43

32 80.57

7579.73

7214.93

1805.40

2662.20

1351908.00

Eq MWH241935.19

25136.80

180886.81

273060.07

13345.60

15595.20

88048.53

2006.40

26964.80

1803.73

7600.00

2006.40

4610.67

587.73

29163.73

5624.00

10082.67

516.80

2229.33

58216.00

Eq MWH1615068.00

55314.60

158936.40

114699.00

Eratic feedwater control. tripped on high water

Condensate pump seal water

899 electrical relay failure

Reverst Power / Runback - TSE Ramp Rate

Runback - TSE Limitation

Cooling water tower outage

Unit #1 Planned 2-year Inspection Outage

Unit #1 Planned 2-year Inspection Outage (After Testing)

Both FD fan inlet dampers frozen.

Reliability Repairs

Reliability Repairs

EHC sytem contamination

Continuation of Reliability Repairs

continuation of reliability repairs


Turbine control valve oscellation due to EHS fluid contamination


DA tank level control bypass valve

Unit Trip due to fan vibration

Turbin Lube Oil System Valves and Piping

MTBFP Trips

lost fire in boiler due to low drum level

Description

Description

Cause

Cause

7201

4283

4283

4290

4283

3344

1480

4283

3412

1799

3310

4304

1700

4304

4499

1799

1999

1999

1420

4283

End

End

1/1/2018 0:00

2/10/2017 13:35

2/13/2017 22:31

6/22/2017 10:45

6/26/2017 13:17

6/29/2017 3:14

6/29/2017 6:12

6/30/2017 7:32

7/2/2017 13:48

7/12/2017 1:27

7/20/2017 13:03

7/28/2017 23:59

8/1/2017 0:00

8/2/2017 0:17

8/2/2017 1:28

8/3/2017 9:49

8/9/2017 20:18

8/20/2017 18:36

9/20/2017 13:54

9/20/2017 21:02

Start1/9/2017 6:09

2/10/2017 13:57

6/26/2017 9:59

6/27/2017 6:53

6/29/2017 3:14

6/29/2017 19:02

7/2/2017 10:30

7/11/2017 17:52

7/20/2017 12:05

7/27/2017 0:01

7/31/2017 14:45

8/1/2017 7:42

8/2/2017 0:37

8/3/2017 6:09

8/9/2017 7:50

8/20/2017 6:44

9/20/2017 10:57

9/20/2017 16:41

10/1/2017 0:00

12/28/2017 0:15

Start1/1/2017 0:00

4/21/2017 0:00

4/24/2017 18:23

5/5/2017 14:05

1/1/2018 0:00

4/21/2017 0:00

4/24/2017 18:23

5/5/2017 14:05

5/13/2017 9:30

PO

PO

SF

U1

U1

U1

SF

MO

U1

PO

U1

U1

MO

U1

U1

U1

PO

PO

LUDINGTON - LUDINGTON 1

3312

9320

4300

4300

3245

7201

condensate pump seal water regulator control air line

Turbine control valve Tripped on High Water

high water boiler feed pump

Turbine control valve

Boiler feed pump turbine turning gear issue

Boiler tunning

Eratic feedwater control. tripped on high water

U1

PO

PE

U1

PO

PO

PO

U1

PO

U1

U1

KARN 3-4 - KARN 4

Event

5/13/2017 21:05

5/26/2017 18:03

6/14/2017 10:20

6/15/2017 8:17

6/16/2017 9:56

5/26/2017 4:39

6/14/2017 10:20

6/15/2017 8:17

6/16/2017 9:56

4283

4306

4283

Event



19

21 91.73

40 6.72

117 10.25

155 6.72

178 1.78

212 7.82

214 7.43

248 0.93

262 7.53

301 528.00

316 12.05

384 8.00

385 0.30

393 7.15

403 5.65

404 6.80

178992.00

4084.95

2712.00

101.70

2280.85

1802.35

2169.20

28620.80

2276.95

3474.75

2276.95

604.55

2649.85

2519.90

316.40

2553.80

2017 Fall Pond Outage

2017 Fall Pond Outage Extension - due to Submetro's Chauvez Rd. Substation Xfrmr Swap

Brush Inspection & Cleaning


Failed bearing & gear in 105 motor-operated switch

Black Start Testing


Unit #1 Planned 2-year Inspection Outage (After Testing)

Brush cleaning & inspection

MTB #1 Deluge Testing


Inspecting for Internal oil cooler water leak - none found (water content only 30ppm)

Brush Cleaning & Inspection


Induction reg out of start up position - Pump Only


7201

4602

3869

4602

4550

4602

4602

7299

4602

7201

7201

4602

4602

3681

9998

4602

2/17/2017 18:15

3/6/2017 13:43

4/19/2017 17:00

5/9/2017 13:44

5/25/2017 8:07

6/20/2017 14:49

7/11/2017 14:26

7/28/2017 0:21

8/15/2017 14:28

10/9/2017 6:45

10/9/2017 18:48

11/13/2017 15:02

11/13/2017 15:20

12/5/2017 19:55

2/13/2017 22:31

12/10/2017 7:00

12/11/2017 7:00

12/10/2017 12:39

12/11/2017 13:48

3/6/2017 7:00

4/19/2017 6:45

5/9/2017 7:01

5/25/2017 6:20

6/20/2017 7:00

7/11/2017 7:00

7/27/2017 23:25

8/15/2017 6:56

9/17/2017 6:45

10/9/2017 6:45

11/13/2017 7:02

11/13/2017 15:02

12/5/2017 12:46

PE

PO

PO

PO

U1

PO

PO

U1

PO

PO

PE

PO

PE

U1

PO

PO



20

Type Eq Hrs1 10.00

55 6.32

2 6.15

4 5.25

57 8.00

58 1.12

93 847.32

94 0.38

95 0.08

105 0.02

122 1.98

144 10.25

179 1.40

180 6.35

196 29.22

245 7.40

250 7.47

276 128.32

315 0.07

330 528.00

342 12.05

396 8.00

397 0.75

444 5.65

446 7.42

447 0.12

6.37

757.63

3915.50

534.80

2425.70

11160.77

2826.80

2852.27

49016.97

25.47

201696.00

4603.10

3056.00

286.50

1966.20

2581.00

40.60

Eq MWH3480.00

2198.20

2140.20

1827.00

2784.00

388.60

316534.39

146.43

31.83

Excess brush/brake dust build-up on the SSG ZVPU governor speed sensors


Exciter trip prevented unit from running


Broken Wicket Gate Shear Pin #12



Broken Shear Pin on Wicket Gate #5

SSG was covered in carbon dust, needed to be cleaned.





Black Start Testing


ZPU Speed Sensor coated in carbon dust - cleaned to resolve issue.

MTB#1 Bank outage required to remove 112 links for Unit #1 2-year Inspection Outage

MTB#1 Bank outage required to remove 112 links for Unit #1 2-year - tagging issues


Station Sump Pump #1 Isolation Valve Failure - Leak causing flooding on 535 Elevation.

Installing 112 Link as part of returning Unit #1 from Periodic Outage

Installing 112 Link as part of returning Unit #1 from Periodic Outage

Unit #2 Planned Outage - Turbine Guide Bearing Modification



Start-up Failure - Brakes sticking.

DescriptionCause7201

7201

4602

3899

7201

7201

7007

7007

7007

4590

4899

3869

4609

4602

7142

4602

4602

End

5/10/2017 13:34

5/19/2017 23:58

6/21/2017 14:24

7/14/2017 14:28

7/29/2017 11:00

8/17/2017 13:03

10/9/2017 6:45

10/9/2017 18:48

11/14/2017 15:00

11/14/2017 15:45

12/10/2017 12:39

12/12/2017 14:25

12/13/2017 6:00 4899

7142

4899

7201

7201

4602

4602

9998

4602

5/18/2017 18:45

6/21/2017 7:00

7/14/2017 7:00

7/24/2017 2:41

8/17/2017 12:59

9/17/2017 6:45

10/9/2017 6:45

11/14/2017 7:00

11/14/2017 15:00

12/10/2017 7:00

12/12/2017 7:00

12/13/2017 5:53

Start1/9/2017 7:01

1/9/2017 17:01

1/12/2017 7:00

1/18/2017 16:20

2/9/2017 7:18

2/9/2017 15:18

2/20/2017 5:59

3/27/2017 15:36

3/27/2017 17:00

3/30/2017 6:59

4/7/2017 19:56

4/19/2017 6:45

5/9/2017 23:06

5/10/2017 7:13

1/9/2017 17:01

1/9/2017 23:20

1/12/2017 13:09

1/18/2017 21:35

2/9/2017 15:18

2/9/2017 16:25

3/27/2017 14:18

3/27/2017 15:59

3/27/2017 17:05

3/30/2017 7:00

4/7/2017 21:55

4/19/2017 17:00

5/10/2017 0:30

PO

PE

PO

U1

PO

PE

PO

PE

PO

PO

SF

PO

PO


Event

PO

SF

SF

PO

U1

PO

U1

PO

PO

U1

SF

PO

PE



21

Type Eq Hrs1 5.40

2 24.17

76 78.88

89 5.60

122 99.87

135 247.50

145 8.53

148 133.25

162 7.08

175 75.28

192 3.88

213 7.10

216 7.40

264 7.05

301 528.00

310 12.05

316 0.15

317 2.83

367 7.12

385 1.75

414 5.65

416 6.50

50.25

949.17

2384.08

586.25

1779.75

2047.50

Eq MWH1684.80

7540.00

24611.60

1876.00

33455.33

82912.50

2858.67

44638.75

2372.92

25219.92

1300.92

2378.50

2479.00

2361.75

176880.00

4036.75


Failed exciter resistor in AVR cabinet due to age - replaced it.

Black Start Testing



Unit #3 Planned Outage - Thrust Bearing & Generator Inspections

Brush inspection & cleaning

Repair work for Unit #3 lower expansion joint chamber

Repair work for Unit #3 lower expansion joint chamber - taking longer than anticipated


MTB#2 Planned Maintenance Outage


MTB#2 Outage

316 had an air leak






Exciter control issue in automatic, started in manual 9 minutes after called-upon.

Leak on 316 air control valve due to bad seal, replaced valve.


DescriptionCause

4602

3999

3999

3869

3620

4602

3620

4899

4602

4602

4602

7201

7201

4609

4899

4602

4609

9998

4/1/2017 15:00

4/11/2017 22:30

4/20/2017 15:10

4/29/2017 19:15

5/8/2017 14:20

6/2/2017 8:18

6/6/2017 14:59

6/19/2017 14:06

7/10/2017 14:24

8/14/2017 14:04

10/9/2017 6:45

10/9/2017 18:48

10/18/2017 6:52

10/19/2017 11:35

11/15/2017 14:07

11/27/2017 7:42

12/10/2017 12:39

1/11/2017 12:24

1/19/2017 16:30

2/21/2017 13:21

3/13/2017 13:49

End4602

3899

7201

4602

12/13/2017 7:00 12/13/2017 13:30

3/28/2017 11:08

4/1/2017 15:00

4/20/2017 6:38

4/24/2017 6:00

5/8/2017 7:15

5/30/2017 5:01

6/6/2017 11:06

6/19/2017 7:00

7/10/2017 7:00

8/14/2017 7:01

9/17/2017 6:45

10/9/2017 6:45

10/18/2017 6:43

10/19/2017 8:45

11/15/2017 7:00

11/27/2017 5:57

12/10/2017 7:00

Start1/11/2017 7:00

1/18/2017 16:20

2/18/2017 6:28

3/13/2017 8:13

PO

PO

PO

MO

U1

PO

PO

PO

PO

PE

SF

U1

PO

SF

PO

PO

PO

U1

PO

PO

MO

ME


Event



22

Type Eq Hrs1 6.63

48 1.43

2 5.25

76 7.32

119 6.08

120 1.07

212 8.53

218 133.25

238 6.80

253 75.28

283 7.48

286 7.65

325 3.08

327 34.97

378 528.00

392 12.05

436 6.63

437 3.82

459 7.72

494 6.07

504 5.65

505 0.30

506 7.25

2858.63

2922.30

1177.83

13357.27

201696.00

4603.10

2533.93

1457.97

2947.77

2117.27

1971.85

104.70

2530.25

Eq MWH2315.03

500.23

1832.25

2553.52

2323.83

407.47

3259.73

50901.50

2597.60

28758.23

High-Cycle fatigue of Shear Pins - Replacing all 20 pins



High-Level on thrust bearing oil reservoir (tub)

High-Level on thrust bearing oil reservoir (tub)


Failed bearing & gear in 105 motor-operated switch

Black Start Testing

11G/4 M-3425A GEN PROTECTION RELAY TRIP. TARGET 24DT #2 VOLT/HZ DEF (DURING PUMP SPIN)



Cooling water valve issue.



Brush inspection & cleaning

Start-up Failure


MTB#2 Planned Maintenance Outage


MTB#2 Outage



X-Ray inspection of 2 shear pins

DescriptionCause

7003

7003

4602

3681

9998

4750

4602

4602

3822

3899

4602

4602

4899

3869

3620

4602

3620

4602

4602

7142

7142

7201

7201

End

10/9/2017 6:45

10/9/2017 18:48

11/4/2017 11:10

11/4/2017 23:25

11/16/2017 14:38

12/5/2017 18:50

12/10/2017 12:39

12/13/2017 2:00

12/14/2017 14:15

10/9/2017 6:45

11/4/2017 4:32

11/4/2017 19:36

11/16/2017 6:55

12/5/2017 12:46

12/10/2017 7:00

12/13/2017 1:42

12/14/2017 7:00

Start1/13/2017 7:00

1/13/2017 17:09

1/18/2017 16:20

2/15/2017 7:05

3/16/2017 7:00

3/20/2017 6:06

4/20/2017 6:38

4/24/2017 6:00

5/12/2017 7:20

5/30/2017 5:01

6/22/2017 6:58

7/13/2017 7:06

8/1/2017 9:06

8/3/2017 6:02

9/17/2017 6:45

1/13/2017 13:38

1/13/2017 18:35

1/18/2017 21:35

2/15/2017 14:24

3/16/2017 13:05

3/20/2017 7:10

4/20/2017 15:10

4/29/2017 19:15

5/12/2017 14:08

6/2/2017 8:18

6/22/2017 14:27

7/13/2017 14:45

8/1/2017 12:11

8/4/2017 17:00

PO

U1

PO

U1

PO

U1

U1

PO

PO

SF

PO

PO

PO

MO

PO

PO

U1

U1

PO

PE

U1

U1

PO


Event



23


2 648.00

3 0.27

4 0.33

5 0.92

6 41.77

7 16.35

8 53.92

9 19.30

10 22.98

12 92.83

13 16.00

57 7.08

60 1.47

61 8.00

62 2.25

100 4.83

119 6.83

146 1498.88

148 0.22

147 0.65

165 6.58

203 1.33

204 3.77

216 7.00

127.33

350.17

15954.87

6245.70

20596.17

7372.60

8779.63

35462.34

6112.00

2705.83

560.27

3056.00

859.50

1846.33

2610.33

572573.44

82.77

Eq MWH791248.00

227232.00

101.87

MOH - Testing

MOH - Testing

MOH - Testing

MOH - Testing

MOH - Testing


Changed oil due to contamination - metallic particles


Additional cleaning due to oil contam. due to loose access panels, bolts not locked

Exciter Issue - Blown snubber fuse


Main Transformer Bank (MTB) #3 Outage - GSU Replacements

Main Transformer Bank (MTB) #3 Outage - GSU Replacements

Main Transformer Bank (MTB) #3 Outage - GSU Replacements (tested in pump-spin)


Black Start Testing

Black Start Testing


MOH of Unit 5

MOH of Unit 5

MOH - Load Rejection Testing



MOH - Pump Testing

MOH - Testing

Description

7200

7200

4602

7053

4602

4602

4609

4602

3620

3620

3620

4602

9998

9998

4602

5/23/2017 16:35

5/24/2017 10:30

6/23/2017 14:20

7/11/2017 11:41

7/12/2017 15:00

7/12/2017 17:15

7/29/2017 11:14

8/10/2017 14:04

11/6/2017 13:54

11/6/2017 15:01

11/6/2017 15:40

11/17/2017 13:38

12/10/2017 8:20

12/10/2017 12:39

7200

7200

7200

7200

7200

7200

7200

7200

7200

7200

End

5/18/2017 18:00

5/19/2017 18:18

Cause4/15/2017 8:00

5/12/2017 8:00

5/12/2017 9:00

5/12/2017 9:51

5/12/2017 11:20

5/14/2017 7:47

5/15/2017 7:23

5/17/2017 21:01

5/17/2017 22:42

5/18/2017 19:19

5/19/2017 19:45

5/23/2017 18:30

6/23/2017 7:15

7/11/2017 10:13

7/12/2017 7:00

7/12/2017 15:00

7/29/2017 6:24

8/10/2017 7:14

9/5/2017 4:01

11/6/2017 14:48

11/6/2017 15:01

11/17/2017 7:03

12/10/2017 7:00

12/10/2017 8:53

12/15/2017 7:00

Start1/1/2017 0:00

4/15/2017 8:00

5/12/2017 8:44

5/12/2017 9:31

5/12/2017 10:25

5/12/2017 14:01

5/14/2017 15:02

5/15/2017 15:06

PO

U1

PO

PE

U1

PO

PO

PO

PE

PO

PO

PO

PO 12/15/2017 14:00

248.30

2514.83

465.33

1314.57

2443.00

PO

PE

PO

PO

PO

PO

PO

PO

PO

PO

PO

PO

Event




24

Type Eq Hrs5 7.28

11 5.25

94 8.00

96 34.08

143 35.10

144 14.30

145 6664.50

Type Eq Hrs4 39.52

20 48.00

24 311.87

25 6.97

55 8.55

62 167.90

75 0.78

87 7.43

94 1.67

7113.00

7488.00

48651.20

1086.80

1333.80

30222.00

141.00

1338.00

300.00

MOH of Unit #6

MOH of Unit #6

Compressor Bleed Valve change out

GT2A Water Wash

Spring Maintenance Outage

Extended Spring Maintenance Outage

GT2A Water Wash for Fall Outage

Phase 2 Fall Periodic Outage

East Boiler Tripped and Failed to ignite on restart

89SS failed to operated

GT2A Tripped - OUTSIDE CUSTOMER TRIP L4CT



Transformer Bank Outage to install 512 Links

Unit needed to stay isolated for cleaning sand build-up in station sump pit

MOH of Unit #6

Description

Description

Cause

Cause

7201

3899

7200

7200

7200

5039

5035

1810

1810

5035

3211

3830

4600

6299

4602

3899

End

12/26/2017 2:59

6/1/2017 0:21

9/9/2017 9:53

10/7/2017 0:06

11/19/2017 7:15

12/7/2017 3:44

1/10/2017 14:01

1/18/2017 21:35

2/18/2017 14:30

2/20/2017 0:36

3/28/2017 17:19

3/29/2017 8:00

1/1/2018 0:00

1/22/2017 15:30

5/8/2017 0:12

6/1/2017 0:21

6/1/2017 7:19

9/9/2017 18:26

10/14/2017 0:00

11/19/2017 8:02

12/7/2017 11:10

End

PE

PO

PO

SF

SF

U1 12/26/2017 1:19

PO

PO

PO

MO

PO

PO


Event

ZEELAND CC - ZEELAND3

Event

Start1/10/2017 6:44

1/18/2017 16:20

2/18/2017 6:30

2/18/2017 14:31

3/27/2017 6:13

3/28/2017 17:42

3/29/2017 8:30

Start1/20/2017 23:59

5/6/2017 0:12

5/19/2017 0:29

Eq MWH2272.40

1638.00

2496.00

10634.00

11793.60

4804.80

2225136.00

Eq MWH

PO

U1

PO

MO



25

Type Eq Hrs4 39.52

21 39.28

24 311.87

25 7.45

44 39.85

56 40.32

58 6.90

64 167.90

77 0.78

Type Eq Hrs4 39.52

28 312.00

29 8.98

73 167.90

86 0.78

Type Eq Hrs14 16.22

39 14.12

44 161.70

49 3.42

52 3.38

103 11.33

134 16.00

30222.00

141.00

Eq MWH8496.08

66768.00

1922.43

36098.50

168.42

Eq MWH2919.00

2541.00

25710.30

543.25

537.95

2040.00

2880.00

Eq MWH7113.00

6167.48

48963.07

1169.65

6256.45

6329.72

1083.30GT2B Water Wash for Fall Outage


East Boiler Tripped and Failed to ignite on restart





East Boiler Tripped and failed to ignite on restart


GT1A WATER WASH


Replace Servo's on PM1 and PM3

GT1A Stackvision not operating properly - lost data logger

Polarizing scheme wiring work

52G Failed to Close


GT2B Water Wash



Repairs to 1A CCW Pump Motor Protective Relay

1A CCW Pump Failed to start - Protective Relay Failure - Ongoing from 8/3 ITC Fault

Description

4720

Cause

1810

1810

3211

3830

Description

Description

1810

5039

5435

5272

5041

9623

3620

5039

5035

End

Cause

Cause2/7/2017 16:12

4/29/2017 14:12

5/12/2017 17:45

5/28/2017 9:57

6/16/2017 23:08

10/25/2017 18:20

1/1/2018 0:00

10/7/2017 0:06

11/19/2017 7:15

Start1/20/2017 23:59

5/19/2017 0:21

6/1/2017 0:21

10/7/2017 0:06

11/19/2017 7:15

1/22/2017 15:30

5/14/2017 16:30

6/1/2017 0:21

6/1/2017 7:48

8/5/2017 15:04

9/12/2017 16:59

9/13/2017 15:24

10/14/2017 0:00

11/19/2017 8:02

1/22/2017 15:30

6/1/2017 0:21

6/1/2017 9:20

10/14/2017 0:00

11/19/2017 8:02

End

1810

End

3730

3730

5035

3211

3830

5039

PE

PO

SF

MO

PO

PO

MO

U1

MO

SF

ZEELAND ST - ZEELAND1

Event

ZEELAND ST - ZEELAND2

Start2/6/2017 23:59

4/29/2017 0:05

5/6/2017 0:03

5/28/2017 6:32

6/16/2017 19:45

10/25/2017 7:00

12/31/2017 8:00

MO

PO

PO

PE

U1

U1

PO

PO

SF

MO

PO


Event


Event

Start1/20/2017 23:59

5/13/2017 1:13

5/19/2017 0:29

6/1/2017 0:21

8/3/2017 23:13

9/11/2017 0:40

9/13/2017 8:30



26

Type Eq Hrs16 11.77

18 1.00

24 0.70

44 0.28

47 39.13

51 161.70

65 8.48

69 57.37

118 11.33

135 92.15

51.00

7044.00

25386.90

1331.88

9006.57

2040.00

16587.00

Eq MWH2118.00

180.00

126.00Static Starter Connect Sequence Trouble Alarm - 89SS Limit Switch hung up

GT1B Auto Tune Sensor Failure, Operator attempted to clear fault - Unit Tripped

GT1B WATER WASH


Replace Ignitor in Can #3

High NOx - Outage to replace Combustion Can Covers fixing High NOx issue

Polarizing scheme wiring work

GT1B Removed from service to conserve gas pressure for other units


Water Wash Drain Valve change out

DescriptionCause

3620

9130

10/25/2017 18:20

12/31/2017 9:15

10/25/2017 7:00

12/27/2017 13:06

1/12/2017 5:28

2/8/2017 8:51

3/14/2017 4:47

4/28/2017 15:37

4/29/2017 0:05

5/6/2017 0:03

5/23/2017 7:01

6/9/2017 4:07

1/12/2017 17:14

2/8/2017 9:51

3/14/2017 5:29

4/28/2017 15:54

4/30/2017 15:13

5/12/2017 17:45

5/23/2017 15:30

6/11/2017 13:29

End5039

5035

5250

9900

5435

5272

5050

9613MO

MO

U1

MO

MO

SF

U1

PO

PO

MO

Event Start

MICHIGAN PUBLIC SERVICE COMMISSION Case No.: U-20068 Exhibit No.: A-4 (DBK-2) Consumers Energy Company Page: 1 of 2 Witness: DBKehoe Date: March 2018

EVENT IDENTIFICATION – OUTAGES1

PO – Planned Outage An outage that is scheduled well in advance and is of a predetermined duration, can last for several weeks, and occurs only once or twice a year. Turbine and boiler overhauls or inspections, testing, and nuclear refueling are typical planned outages. For a planned outage, all of the specific individual maintenance and operational tasks to be performed are determined in advance and are referred to as the "original scope of work." The general task of repairing turbines, boilers, pumps, etc. is not considered a work scope because it does not define the individual tasks to be performed. For example, if a general task such as repair boiler is considered the work scope, it is impossible to conclude that any boiler work falls outside of the original scope of work. Discovery work and rework which render the unit out of service beyond the estimated PO end date are not considered part of the original scope of work. A planned extension may be used only in instances where the original scope of work requires more time to complete than the estimated time. For example, if an inspection that is in the original scope of work for the planned outage takes longer than scheduled, the extra time should be coded as an extension (PE). However, if damage found during the inspection results in an extension of the outage, the extra time required to make repairs should be coded as forced outage. MO – Maintenance Outage An outage that can be deferred beyond the end of the next weekend (defined as Sunday at 2400 hours or as Sunday turns into Monday), but requires that the unit be removed from service, another outage state, or Reserve Shutdown state before the next Planned Outage (PO). Characteristically, a MO can occur any time during the year, has a flexible start date, may or may not have a predetermined duration, and is usually much shorter than a PO. Discovery work and re-work which render the unit out of service beyond the estimated MO end date are not considered part of the original scope of work. A maintenance extension may be used only in instances where the original scope of work requires more time to complete than the estimated time. For example, if an inspection that is in the original scope of work for the outage takes longer than scheduled, the extra time should be coded as an extension (ME). If the damage found during the inspection is of a nature that the unit could be put back on-line and be operational past the end of the upcoming weekend, the work could be considered MO or ME. If the inspection reveals damage that prevents the unit from operating past the upcoming weekend, the extended work time should be Forced Outage (U1, U2, or U3).

lhblair

Text Box


MICHIGAN PUBLIC SERVICE COMMISSION Case No.: U-20068 Exhibit No.: A-4 (DBK-2) Consumers Energy Company Page: 2 of 2 Witness: DBKehoe Date: March 2018 PE – Planned Outage Extension GADS defines a planned outage extension as an extension of a Planned Outage (PO) beyond its estimated completion date. This means that at the start of the PO, the outage had an estimated duration (time period) for the work and a date set for the unit to return to service. All work during the PO is scheduled (part of the original scope of work) and all repair times are determined before the outage started. ME – Maintenance Outage Extension GADS defines a maintenance outage extension as an extension of a Maintenance Outage (MO) beyond its estimated completion date. This means that at the start of the MO, the outage had an estimated duration (time period) for the work and a date set for the unit to return to service. All work during the MO is scheduled (part of the original scope of work) and all repair times are determined before the outage started. SF – Startup Failure This is an outage that results when a unit is unable to synchronize within a specified startup time following an outage or reserve shutdown. The startup period for each unit is determined by the operating company. It is unique for each unit, and depends on the condition of the unit at the time of startup (hot, cold, standby, etc.). A startup period begins with the command to start and ends when the unit is synchronized. SF begins when a problem preventing the unit from synchronizing occurs. The SF ends when the unit is synchronized, another SF occurs, or the unit enters another permissible state. U1 - Unplanned (Forced) Outage – Immediate This is an outage that requires immediate removal of a unit from service, another outage state, or a reserve shutdown state. This type of outage usually results from immediate mechanical/electrical/hydraulic control system trips and operator-initiated trips in response to unit alarms. U2 - Unplanned (Forced) Outage – Delayed This is an outage that does not require immediate removal of a unit from the in-service state, instead requiring removal within six hours. This type of outage can only occur while the unit is in service. U3 – Unplanned (Forced) Outage – Postponed This is an outage that can be postponed beyond six hours but requires that a unit be removed from the in-service state before the end of the next weekend (Sunday at 2400 or before Sunday turns into Monday). This type of outage can only occur while the unit is in service. 1From January 2015 GADS data reporting instructions.

Case No: U-20068Exhibit No.: A-5 (DBK-3)

Page: 1 of 128Witness: DBKehoeDate: March 2018

Sequence Number: Campbell Unit 1-2017-1Plant/Unit: Campbell Unit 1MW Derate:

Event Year: 2017Event Number: 34

Start Date: 2/17/2017 1:52End Date: 3/17/2017 19:12Outage Type: MO

Duration (Hours): 688.33MWh Loss: 178966.66

NERC Cause Code: 920NERC Cause Code Description: Other Slag and Ash Removal ProblemsRoot Cause Description: High furnace-exit gas temperature, resulting in molten ash being

transported to and solidifying in the backpass.

Event Description: Maintenance OutageAdditional Description:

MICHIGAN PUBLIC SERVICE COMMISSIONConsumers Energy Company

INFORMATION FOR UNIT - Campbell Unit 1PERIODIC OUTAGE

lhblair

Text Box




Mode of Failure: At normal temperatures within the furnace, coal fly ash exceeds its ash fusion temperature. Ash fusion temperature is dependent on the specific chemical makeup of the coal being burned. Above the fusion temperatures, the ash will become "sticky" as it transitions from a solid to a semi-solid / liquid phase. The boiler is designed for this sticky ash to plate out on the furnace walls and at the top of the furnace, where it can be removed by soot blowing equipment. As heat is transferred to the waterwall and superheat tubing within the furnace, the resulting gas temperature is dropped to below the ash fusion temperature, and the ash being carried to the backpass should have a powdery, dry consistency. If the furnace-exit gas temperature (FEGT) is still too high, the semi-molten ash will plate out on the more tightly spaced tubing in the backpass, creating hard solid pluggage. The pluggage decreases the duct cross-section, resulting in increased gas velocities in these areas. This increased velocity leads to ash erosion on the tubing and eventual tube failure at unplanned times requiring repairs. Soot blowers in the backpass will often keep ash from building up on tubes. However, if FEGT is too high, and large deposits begin to form between the tubes, the soot blowers are often not able to remove the ash.

Final Corrective Action: Mechanically removed hard ash deposits between tubes, opening lanes between tube bundles to allow normal gas flow.

Mechanism Causing: High furnace-exit gas temperature resulting in semi-solid "sticky" ash being carried into the backpass. See explanation above.

Final Root Cause High furnace-exit gas temperature resulting in semi-solid "sticky" ash being carried into the backpass. See explanation above.

Scope to Correct Root Cause: Continue to control FEGT through online furnace cleaning and burner tuning.

Additional Scope:

If outage Extended for AdditionalWork & Why:





Start Date: 10/27/2017 6:28End Date: 12/14/2017 16:21Outage Type: PO


NERC Cause Code: 0360NERC Cause Code Description: BurnersRoot Cause Description: Regulatory Compliance

Event Description: PO-critical path:burner replacementAdditional Description:

Mode of Failure: Planned activity to maintain regulatory complianceFinal Corrective Action: Replacement of half of the burner assembliesMechanism Causing: Regulatory ComplianceFinal Root Cause Planned compliance activityScope to Correct Root Cause: N/AAdditional Scope: N/A










NERC Cause Code: 4609NERC Cause Code Description: Other Exciter ProblemsRoot Cause Description:

Event Description: Exciter PMT; exciter work was original outage scopeAdditional Description: A turbine overspeed test was due pre/post Fall 2018 periodic outage. The

overspeed test was performed post-outage. The overspeed test is typically performed on the startup-excitation breaker. During the overspeed test there was a "fail to close" on 4160V startup-excitation breaker. Operations successfully performed the overspeed test on the "B" machine on the main-excitation breaker, but the machine tripped on V/Hz after the test. While electricians were troubleshooting the 4160V startup-excitation breaker, the turbine heated unevenly, causing the rotor to bow, locking the rotor. A portion of this event time was spent troubleshooting the breaker, the remaining time was spent on turning gear to evenly heat the turbine rotor so that the overspeed test could be repeated.





Mode of Failure: 4160V startup-excitation breaker: breaker issue, breaker swapped and resolvedTurbine shaft bow: unclear operations procedures on actions if overspeed test is delayed in the middle of the test

Final Corrective Action: Revised turbine overspeed procedures to provide direction in the event the overspeed is delayed to prevent uneven turbine heating

Mechanism Causing: See aboveFinal Root Cause See aboveScope to Correct Root Cause: See aboveAdditional Scope: See above


See above





Start Date: 12/16/2017 0:07End Date: 12/16/2017 1:14Outage Type: SF



Event Description: Exciter troubleshootingAdditional Description: Excitation system failed to transfer from startup field breakers to main field

breakers. When this fail to transfer occurs, the lock-out-relay is actuted and the unit must be brought down to turning gear then roll-up again.

Mode of Failure: Unknown at this timeFinal Corrective Action: Unknown at this timeMechanism Causing: Unknown at this timeFinal Root Cause Unknown at this timeScope to Correct Root Cause: Unknown at this time





Additional Scope: This has been a longstanding issue on this unit. A lot of troubleshooting has gone into understanding why the automatic voltage regulator (AVR) intermittently has issues transferring from the startup field breakers to the main field breakers. Siemens was brought in during the Fall 2017 periodic outage to perform complete checkout and tuning of the AVR. No major issues were noted during this maintenance. Also, the field breakers have been sent out for complete overhaul in the past 5 years. No root cause has been found. CE does have plans to upgrade the controls (obsolete) on the AVR in 2019.


See above







NERC Cause Code: 4460NERC Cause Code Description: Turbine Overspeed Trip Test...Root Cause Description:

Event Description: Turbines on gear & working procedure to perform overspeed test; online 0430

Root cause Description:

Additional Description: This was a yearly required turbine overspeed trip test. The unit was placed on line to warm up. The unit was then brought offline to perform the test. The "B" train is tested first and it was performed satisfactorily. The excittation system had issues wich prevented rolling back up to test the "A" turbine. The unit was placed on gear, however, the turbine drains were not opened. this allowed the buildup of water in the turbine which caused a temperature gradient from upper shell to lower shell which caused the shells to bow and locking onto the rotor. The prewarming procedure was then entered and after several hours the unit was able to be placed on gear again. The unit was again started up and due to the length of time offline had to be placed online for several hours to heat the rotors prior to completing the remaineder of the overspeed trip test.





Mode of Failure: Temporary shell bowing.Final Corrective Action: allow shell tempt to equalize. Revise procedure.Mechanism Causing: Temperature gradient from upper shell to lower shellFinal Root Cause Turbine drains not opened following the tripScope to Correct Root Cause: procedures revised.Additional Scope: none


see above story








Event Description: Planned & scheduled turbine overspeed (1A turbine)Additional Description: This was a yearly required turbine overspeed trip test. The unit was placed on line

to warm up. The unit was then brought offline to perform the test. The "B" train is tested first and it was performed satisfactorily. The excittation system had issues wich prevented rolling back up to test the "A" turbine. The unit was placed on gear, however, the turbine drains were not opened. this allowed the buildup of water in the turbine which caused a temperature gradient from upper shell to lower shell which caused the shells to bow and locking onto the rotor. The prewarming procedure was then entered and after several hours the unit was able to be placed on gear again. The unit was again started up and due to the length of time offline had to be placed online for several hours to heat the rotors prior to completing the remaineder of the overspeed trip test.



see above story










Event Description: Exciter troubleshootingAdditional Description: Excitation system failed to transfer from startup field breakers to main field

breakers. When this fail to transfer occurs, the lock-out-relay is actuted and the unit must be brought down to turning gear then roll-up again.

Mode of Failure: Unknown at this timeFinal Corrective Action: Unknown at this timeMechanism Causing: Unknown at this timeFinal Root Cause Unknown at this timeScope to Correct Root Cause: Unknown at this time





Additional Scope: This has been a longstanding issue on this unit. A lot of troubleshooting has gone into understanding why the automatic voltage regulator (AVR) intermittently has issues transferring from the startup field breakers to the main field breakers. Siemens was brought in during the Fall 2017 periodic outage to perform complete checkout and tuning of the AVR. No major issues were noted during this maintenance. Also, the field breakers have been sent out for complete overhaul in the past 5 years. No root cause has been found. CE does have plans to upgrade the controls (obsolete) on the AVR in 2019.


See above








Event Description: unit startup, post-overspeedAdditional Description: This was a yearly required turbine overspeed trip test. The unit was placed on line




see above story









NERC Cause Code: 0770NERC Cause Code Description: Other Boiler Recirculation Problems...Root Cause Description: Root Cause determination in process

Event Description:BCWP differential low; 1D BCWP & BCWP ISWBP - original outage scope

Additional Description:

Mode of Failure: Root Cause determination in processFinal Corrective Action: Root Cause determination in processMechanism Causing: Winding FailureFinal Root Cause Root Cause determination in processScope to Correct Root Cause: Root Cause determination in processAdditional Scope:











Event Description: unit startup - ramp; online at 1733, released to ES&T 12/17 @ 0114Additional Description: This was a yearly required turbine overspeed trip test. The unit was placed on line




see above story





Sequence Number: Campbell unit 1-2017-14Plant/Unit: Campbell unit 1MW Derate:




NERC Cause Code: 4460NERC Cause Code Description: Turbine Overspeed Trip Test...Root Cause Description: Planned Outage activity

Event Description: Planned & scheduled turbine overspeed (1B turbine)Additional Description: A turbine overspeed test was due pre/post Fall 2018 periodic outage. The

overspeed test was performed post-outage. The overspeed test is typically performed on the startup-excitation breaker. Operations successfully performed the overspeed test on the "B" machine on the main-excitation breaker. This completed the B Overspeed trip. This covers the time period from the first overspeed until the unit was tripped on V/Hz.

Mode of Failure: successful completion of B overspeed test, followed by coast down until trip on V/Hz.

Final Corrective Action: Revised turbine overspeed procedures to provide direction in the event the overspeed needs to be delayed on the Main breaker and to place the AVR to manual.

Mechanism Causing: See aboveFinal Root Cause See aboveScope to Correct Root Cause: See aboveAdditional Scope: See above


See above


INFORMATION FOR UNIT - Campbell unit 1PERIODIC OUTAGE







NERC Cause Code: 4280NERC Cause Code Description: turbine lube oil pumpsRoot Cause Description: Mechanical failure due to lack of maintenance.

Event Description: immediate failure of the turbine lube oil auxiliary oil pumpAdditional Description: Auxiliary oil pump failure

Mode of Failure: Bearings and wear rings failed causing pump shaft to bend and pumpcasing to break.

Final Corrective Action: Rebuilt pump and replaced casing with used. New shaft was made. Motor was replaced.

Mechanism Causing: Wearings locked onto pump shaft.Final Root Cause Lack of maintenance resulting in wear rings losing interference fit and

locking onto pump shaft and casing.Scope to Correct Root Cause: Rebuild pump at no less than every 10 years. Replace wear rings at each

inspection.Additional Scope: Tank Drained and Cleaned. FME inspections










NERC Cause Code: 4289NERC Cause Code Description: turbine - other lube oil system problemsRoot Cause Description: Mechanical failure due to Aux oil pump failure

Event Description: Turbine lube oil system malfunctionAdditional Description: Oil spraying in the oil tank causing excessive oil vapors.

Mode of Failure: Flange with yielded boltingFinal Corrective Action: Yielded bolting was replaced. Additional means to lock hardware was

applied.Mechanism Causing: Auxilliary oil pump failure was violent enough to yield neighboring flange

bolting.Final Root CauseScope to Correct Root Cause:Additional Scope:








Start Date: 2/13/2017 23:59End Date: 2/20/2017 14:54Outage Type: ME


NERC Cause Code: 4289NERC Cause Code Description: turbine - other lube oil system problemsRoot Cause Description: OEM design deficiency

Event Description: Turbine lube oil system malfunctionAdditional Description: Fluid drive leaking oil

Mode of Failure: Oil leak.Final Corrective Action: Fluid drive oil deflectors sealed up. Fluid drive filled to bottom of site glass.

Mechanism Causing: High oil level in the fluid drive.Final Root Cause Fluid drive overfilled with oil.Scope to Correct Root Cause: Fluid drive needs new sight glass mounted lower on the base. Surge tank

may be added in the future.Additional Scope: Throttle valve gasket failure during shutdown.










NERC Cause Code: 3401NERC Cause Code Description: start-up feedwaterRoot Cause Description: 31Y and a 41A relay were found with open coils.

Event Description: Ceased startup activities; gen field breaker & SUBFP issuesAdditional Description: Aux relays failed in the voltage regulator preventing the field breaker from closing.

Under normal circumstances a failure of the 31Y aux relay would not cause a boiler trip, but due to the 41A aux relay having been failed at the same time a boiler trip was initiated. The 41A had most likely failed at some previous date and as long as it was the only failure in the system no indication or abnormal running conditions would be noticed.

Mode of Failure: Age of relays and number of operations exceded life cycle of relay.

Final Corrective Action: Replaced Relays and tested all similar relays in the voltage regulator

Mechanism Causing: Age of relays. Relays are not designed for maintenance. They are designed to run to failure. Some of these relays in this cabinet are over 20 years old.

Final Root Cause Coils in the relay burn up after years of useScope to Correct Root Cause: Test and replace aux relays as needed during outages Additional Scope: Write notification for replacement plan








Start Date: 7/31/2017 18:59End Date: 8/4/2017 20:17Outage Type: U1


NERC Cause Code: 3730NERC Cause Code Description: transmission equip beyond 1st substationRoot Cause Description: A modification to replace the substation fault recorder that took place

about 17 years earlier resulted in a current transformer (CT) for a current polarizing scheme to be wired backwards. This caused the campbell plant to be susceptible to false trips on external grid faults. JHC1 lost power during startup because the 799 startup breaker tripped during an external ground fault because of the wiring error. At the time of the event, JHC2 was online. JHC2 briefly remained online, however operators removed JHC2 from service due to complications from the loss of power on Unit 1. Air compressors essential for operations of the Pulse Jet Fabric Filter (PJFF) that are common to JHC 1&2 were being powered from Unit 1. These air compressors lost power which ultimately resulted in operators removing Unit 2 from service. When Unit 2 was removed from service all station power was lost to JHC 1&2 (because there was no startup power due to the 799 trip). This resulted in an uncontrolled shutdown and the blown condenser rupture discs.

Event Description: 345 kV line fault offsite of JHC, ruptured disc replaced





Additional Description: See root cause description above

Mode of Failure: Protective relay operation as a result of a wiring error and an external fault

Final Corrective Action: Wiring error was corrected, the protective scheme was testedMechanism Causing: Protective relay operation as a result of a wiring error and an external fault

Final Root Cause Wiring errorScope to Correct Root Cause: Wiring error was corrected, the protective scheme was testedAdditional Scope: Similar protective schemes were tested at all other Consumers Energy

generating stations








NERC Cause Code: 9900NERC Cause Code Description: operator errorRoot Cause Description: During turbine trip testing, the operator released the Test Lever prior to

returning the Trip and Reset Lever to the normal position, resulting in the turbine trip.

Event Description: Turbine trip during valve testAdditional Description: Operator failed to follow the test procedure.

Increased supervisory oversight during all turbine testing evolutions. Addition of a trip test lever holding device to further prevent accidental tripping.

Mode of Failure: Human ErrorFinal Corrective Action: The Turbine Test Lever was released prior to moving the Trip and Reset

Lever to the normal position.Mechanism Causing: Remedial operator training, along with increased supervisory oversight.

Final Root CauseScope to Correct Root Cause:Additional Scope:










NERC Cause Code: 3401NERC Cause Code Description: start-up feedwater pumpRoot Cause Description: Pump failure due to lack of procedural direction

Event Description: SUBFP failure;Additional Description: During previous start up the pump was run at less than min flow which

resulted in pump failure.

Mode of Failure: Thrust event caused from flashing in the pump.Final Corrective Action: Pump rotating element was replaced.Mechanism Causing: Water flashing to steam resulting in unbalanced loads on the balance disk

Final Root Cause Pump run at less than min flowScope to Correct Root Cause: Alarm added to notify operations of min flow condition with response to

imediately remove pump from service.Additional Scope: N/A


N/A









NERC Cause Code: 0640NERC Cause Code Description: start-up system valvesRoot Cause Description: Galled eye bolt threads caused the packing pusher to bind and resulted in

improper applied torque to packing rings.

Event Description: HP Superheat stop valve (2-61-FV-200A) packing failureAdditional Description: Steam blew through the packing.

Mode of Failure: Steam blew through the packing rings. Final Corrective Action: Refurbished the packing pusher, replaced eye bolt studs with new, installed

packing per vendor recommendations and updated the maintenance procedure to reflect changes.

Mechanism Causing: Improper packing torque.Final Root Cause Galled eye bolt studs didn't allow proper packing torque.Scope to Correct Root Cause: Replaced packing components and changed installation procedure.

Additional Scope:










NERC Cause Code: 3431NERC Cause Code Description: other feedwater valves/ HP /IP turbine shell instrumentation steam leak.

SUBFP oil leak.Root Cause Description: Valve significantly erroded/ thermal well failed/ sealing surfaces not sealed

up.

Event Description: 2-30-FV-066 rebuildAdditional Description: The unit was off line for other issues. Plant operations and maintenance

decided to transition to a maintenance outage to fix several items of similar durations including the 2-30-FV-066 valve.

Mode of Failure: Valve not operating well. Inspection revealed significant errosion on the internal components.

Final Corrective Action: Replaced valve internal components. Mechanism Causing: Errosion due throttling of the Recirc FCV. Final Root Cause Errosion due throttling of the Recirc FCV. Scope to Correct Root Cause: Replaced valve internal components. Additional Scope: none at this time










NERC Cause Code: 4263NERC Cause Code Description: Turbine Reheat Stop Valves...Root Cause Description: Foreign object deposition compromising valve bushing to shaft clearance.

Event Description: Work on left RHSV during MO. Maintnenace and operation groups chose to repair equipment for Unit reliability.

Additional Description: Valve will not move freely during testing evolutions.

Mode of Failure: Exfolliation of scale from steam lines compromising the bushing to shaft clearance, causing the valve to stick, and not move freely during valve testing.

Final Corrective Action: Disassemble, inspect and repair valve.Mechanism Causing: Scale from the steam lines getting trapped between the bushing and shaft

fit areas.Final Root Cause Foreign object deposition compromising valve bushing to shaft clearance.

Scope to Correct Root Cause: Disassemble valve, and restore all bushing to shaft clearances by honing bushings, and polishing the shaft bushing fit areas. Reassemble valve, and perform PMT.

Additional Scope:










NERC Cause Code: 3690NERC Cause Code Description: Station Service Power Distribution System - GenerationRoot Cause Description: N/A

Event Description: cleaning of 77B load centerAdditional Description: Extension of Maintenance Outage within an economic outage to allow

maintenance of Load Center 77B. Load Center 77B requires a dual 1&2 unit outage. This was placed in scope because of the rare opportunity.

Mode of Failure: N/AFinal Corrective Action: N/AMechanism Causing: N/AFinal Root Cause N/AScope to Correct Root Cause: N/AAdditional Scope: N/A


Extension of Maintenance Outage within an economic outage to allow maintenance of Load Center 77B. Load Center 77B requires a dual 1&2 unit outage. This was placed in scope because of the rare opportunity.









NERC Cause Code: 4281NERC Cause Code Description: Turbine Lube Oil Coolers…Air Side Seal Oil CollerRoot Cause Description: Coller tube bundle installed into cooler shell with the incorrect flowpath

orientation.

Event Description: Reliability work for summer runAdditional Description: Difficulty maintaining air side seal oil temperature.

Mode of Failure: Cooler tube bundle installed incorrectly causing diminished flow.Final Corrective Action: Disassembled and cleaned cooler. Reinstalled tube bundle with the proper

orientation.Mechanism Causing: Diminished flow through cooler.Final Root Cause Tube bundle installed into cooler shell improperly.Scope to Correct Root Cause: Disassembled and cleaned cooler. Reinstalled tube bundle with the proper

orientation.Additional Scope:










NERC Cause Code: 4263NERC Cause Code Description: Turbine Reheat Stop Valves...Root Cause Description: Foreign object deposition compromising valve bushing to shaft clearance.

Event Description: Work on left RHSV during MO. Maintnenace and operation groups chose to repair equipment for Unit reliability.

Additional Description: Valve will not move freely during testing evolutions.

Mode of Failure: Exfolliation of scale from steam lines compromising the bushing to shaft clearance, causing the valve to stick, and not move freely during valve testing.

Final Corrective Action: Disassemble, inspect and repair valve.Mechanism Causing: Scale from the steam lines getting trapped between the bushing and shaft

fit areas.Final Root Cause Foreign object deposition compromising valve bushing to shaft clearance.

Scope to Correct Root Cause: Disassemble valve, and restore all bushing to shaft clearances by honing bushings, and polishing the shaft bushing fit areas. Reassemble valve, and perform PMT.

Additional Scope:










NERC Cause Code: 4460NERC Cause Code Description: Turbine Overspeed Trip Test...Root Cause Description: Insurance Requirement

Event Description: Required & scheduled turbine overspeed trip testing.Additional Description: The Turbine Overspeed Trip Testing is a yearly insurance requirement to

ensure the turbine protection system is functional.

Mode of Failure: N/AFinal Corrective Action: N/AMechanism Causing: N/AFinal Root Cause Insurance RequirementScope to Correct Root Cause: N/AAdditional Scope:










NERC Cause Code: 3431NERC Cause Code Description: other feedwater valves/ HP /IP turbine shell instrumentation steam leak.

SUBFP oil leak.Root Cause Description: Valve significantly erroded/ thermal well failed/ sealing surfaces not sealed

up.

Event Description: 2-30-FV-066 rebuildAdditional Description: The unit was off line for other issues. Plant operations and maintenance

decided to transition to a maintenance outage to fix several items of similar durations including the 2-30-FV-066 valve.

Mode of Failure: Valve not operating well. Inspection revealed significant errosion on the internal components.

Final Corrective Action: Replaced valve internal components. Mechanism Causing: Errosion due throttling of the Recirc FCV. Final Root Cause Errosion due throttling of the Recirc FCV. Scope to Correct Root Cause: Replaced valve internal components. Additional Scope: none at this time










NERC Cause Code: 3690NERC Cause Code Description: Station Service Power Distribution System - GenerationRoot Cause Description: N/A

Event Description: cleaning of 77B load centerAdditional Description: Extension of Maintenance Outage within an economic outage to allow

maintenance of Load Center 77B. Load Center 77B requires a dual 1&2 unit outage. This was placed in scope because of the rare opportunity.



Extension of Maintenance Outage within an economic outage to allow maintenance of Load Center 77B. Load Center 77B requires a dual 1&2 unit outage. This was placed in scope because of the rare opportunity.





Sequence Number: Karn Unit 1-2017-1Plant/Unit: Karn Unit 1MW Derate:




NERC Cause Code: 4293NERC Cause Code Description: turbine hydralic systems pipes and valvesRoot Cause Description: pinched oring due to misaligned flange

Event Description: oil leak on HPU systemAdditional Description:

Mode of Failure: Oring failedFinal Corrective Action: Replaced oringMechanism Causing: misalignmentFinal Root Cause pinched oring/misaligned flangeScope to Correct Root Cause: Replaced oringAdditional Scope:



INFORMATION FOR UNIT - Karn Unit 1PERIODIC OUTAGE







NERC Cause Code: 4860NERC Cause Code Description: generator neutral grounding equipmentRoot Cause Description: HSW 4160 breaker failed coil

Event Description: 4160 Breaker failureAdditional Description:

Mode of Failure: HSW 4160 breaker failed coilFinal Corrective Action: Repaired coilMechanism Causing:Final Root Cause Excessive cycling of the breakerScope to Correct Root Cause: Repaired coilAdditional Scope:










NERC Cause Code: 4601NERC Cause Code Description: exciter field RheostatRoot Cause Description: broken lead lug at Rheostat

Event Description: SF for field reostatAdditional Description:

Mode of Failure: Broken leadFinal Corrective Action: Repaired the leadMechanism Causing:Final Root Cause End of life.. Old cable/leads - FatigueScope to Correct Root Cause: Repaired the leadAdditional Scope:










NERC Cause Code: 3210NERC Cause Code Description: circulating water pumpsRoot Cause Description: Fitting failure, causing steam leak

Event Description: Stop the job on BCWPAdditional Description: Crew stopped the start up causing the outage extension for the steam leak.

Once it was evaluated closer, the team determined it was safe to run the unit. 2.4hr delay was to ensure safety of operators and equipment.

Mode of Failure: Fitting failed, causing steam leakFinal Corrective Action: Notifications and plans are in place to repair this leak during the next

outage. It is a priority #1 order.Mechanism Causing: Unknown until we take it apart and fix it. Final Root Cause Unknown until we take it apart and fix it. Scope to Correct Root Cause: Replace or weld repair the fitting, will make that determination once a

weld inspector can thoroughly inspect it next outage.Additional Scope:










NERC Cause Code: 1040NERC Cause Code Description: First Superheater Leaks Root Cause Description: The failure mechanism was a weld failure performed during the 2015-2016

outage.

Event Description: superheater leakAdditional Description: RH furnace radiant superheater

Mode of Failure: Weld FailureFinal Corrective Action: Tube was weld repaired under waranty by contractor. Mechanism Causing: Steam LeakFinal Root Cause Weld FailureScope to Correct Root Cause: Tube was weld repaired under waranty by contractor. Additional Scope: A second leak was found in the LT horizontal RH Element 33. This leak was

found on 2/27/17 during the post shutdown vacuum test and repaired by plant resources on 3/7/17 @ 1644.


The outage was extended to perform a flush of the LTRH to remove damaging sulfates and mitigate accumulating damage. Scope added on 3/6/17. Outage extended again after post repair air test found a second leak in the RH radiant superheater. This repair was also completed under waranty by contractor and unit restored on 3/21/17 @ 0100.









NERC Cause Code: 4260NERC Cause Code Description: Turbine Main Stop ValvesRoot Cause Description: Valve installation error

Event Description: repair south throttle valveAdditional Description:

Mode of Failure: The OEM delivered and installed the valve incorrectly. The stem to crosshead connection was loose, causing a bending moment in the stem every time the valve was cycled.

Final Corrective Action: The valve was disassembled on-site and re-assembled correctly by the OEM.

Mechanism Causing: Assemly Error by OEMFinal Root Cause Valve installation errorScope to Correct Root Cause: The valve was disassembled on-site and re-assembled correctly by the

OEM.Additional Scope:










NERC Cause Code: 1599NERC Cause Code Description: Other Miscellaneous Boiler Air and Gas System Prob...Root Cause Description: Repair SH/RH gas distribution dampers

Event Description: Karn 1 MO for boiler damper repairAdditional Description: Repair SH/RH gas distribution dampers – repair leaks on SH/RH bottom ash

pits

Mode of Failure: ash build up causing damper to bind while attempting to closeFinal Corrective Action: Removed ash by vacuumingMechanism Causing: Excessive ash build up downstream of valves due to extended on-line

operationsFinal Root Cause Ash layout due to gas flow distribution irregularitiesScope to Correct Root Cause: Added PM activities to inspect during outages and removed ash build up.

Additional Scope:


Karn 1 RH and SH ash pit refractory repairs were necessary and performed during the outage.









NERC Cause Code: 1090NERC Cause Code Description: Other Boiler Tube LeaksRoot Cause Description: On 11/28 during a RH air test a leak was found in an old weld on the LTRH

east inlet header drain line.

Event Description: MO for boiler leakAdditional Description:

Mode of Failure: Weld failure from an old weld. Final Corrective Action: Repaired by weld buildup. Mechanism Causing: Weld defectFinal Root Cause Weld defectScope to Correct Root Cause: Defect ground out and weld overlay applied to damaged area.Additional Scope: On November 26, during a boiler air test a leak is identified on the fireside

surface of a boiler tube on the lower slope of the SH furnace. Probable cause of leak is attributed to blunt impact from a clinker fall. Section of tube replaced.










NERC Cause Code: 1090NERC Cause Code Description: Other Boiler Tube LeaksRoot Cause Description: Leak on RH Inlet header drain


Mode of Failure: Weld defectFinal Corrective Action: ground out laced upMechanism Causing: Porosity in original weld.Final Root Cause Weld DefectScope to Correct Root Cause: Excavate old weld and repair.Additional Scope:


12/1/17 While completing greasing on the PJFF manifolds for K1 – contractor found all the pulse pipes for 1A2 were broken.









NERC Cause Code: 4293NERC Cause Code Description: Turbine Hydraulic System Pipes And Valves...Root Cause Description: pinched oring due to misaligned flange












NERC Cause Code: 1599NERC Cause Code Description: Other Miscellaneous Boiler Air and Gas System Prob...Root Cause Description: Ash piled under damper blade

Event Description: Karn 1 MO for boiler damper repairAdditional Description:

Mode of Failure:Final Corrective Action: Vacuumed ash out of area, damper stroked freely.Mechanism Causing:Final Root Cause Normal ash buildup (unpredictable)Scope to Correct Root Cause: N/AAdditional Scope: Ash pit repairs, cleaning ash pit (ash piled up past lower slope)










NERC Cause Code: 1599NERC Cause Code Description: Other Miscellaneous Boiler Air and Gas System Prob...Root Cause Description:

Event Description: Karn 1 MO for boiler damper repairAdditional Description:

Mode of Failure:Final Corrective Action: Repaired breakerMechanism Causing: BindingFinal Root Cause Breaker binding, not racking properlyScope to Correct Root Cause: Pulled breaker, cleaned, repaired and greased. Additional Scope:


SDA Breaker did not show connected when racked in, needed repair









NERC Cause Code: 1599NERC Cause Code Description: Other Miscellaneous Boiler Air and Gas System Prob...Root Cause Description:

Event Description: Maint extensionAdditional Description:

Mode of Failure:Final Corrective Action:Mechanism Causing: Weld at nippled failedFinal Root Cause Fatigue failureScope to Correct Root Cause: cut off nipple, grind down to good material and reweld with post weld x-

rayAdditional Scope:


Startup issues with BCWP









NERC Cause Code: 1090NERC Cause Code Description: Other Boiler Tube Leaks...Root Cause Description: Reheat Tube leak - Weld Defect

Event Description: MO for boiler leakAdditional Description: Reheat leak identified on East Reheat Inlet Header drain line, weld defect

from original plant construction

Mode of Failure: Weld QualityFinal Corrective Action: Ground out and repairedMechanism Causing:Final Root Cause Weld defectScope to Correct Root Cause:Additional Scope: Boiler tube failure on lower slope waterwall - Clinker impact










NERC Cause Code: 1090NERC Cause Code Description: Other Boiler Tube Leaks...Root Cause Description:


Mode of Failure:Final Corrective Action: replaced beams and strutsMechanism Causing: Rusting due to moistureFinal Root Cause Discovery once the duct work was opened.. Additional work was identified

and required to fix in order to ensure safety.Scope to Correct Root Cause: Repaired additional struts and beams that were rotted and failing inside

the duct work.Additional Scope:


Difference between original duration estimate and actual repair duration once scope was fully identified.









NERC Cause Code: 4293NERC Cause Code Description: Turbine Hydraulic System Pipes And Valves...Root Cause Description: Failed fitting.

Event Description: EHC LeakAdditional Description:

Mode of Failure: North side of EHC, next to HP. Compression fitting failure.Final Corrective Action: Replaced fitting, secured with fabricated guard.Mechanism Causing: Material defect.Final Root Cause Material defect.Scope to Correct Root Cause: Replaced fittingAdditional Scope:


N/A









NERC Cause Code: 4267NERC Cause Code Description: Turbine Control Valve TestingRoot Cause Description: Material Defect in LVDT connectors

Event Description: Unit Trip during Valve TestAdditional Description:

Mode of Failure: Turbine tripFinal Corrective Action: Replace LVDT with higher qualityMechanism Causing: False signal (blocked steam path).Final Root Cause Low quality connectors on LVDT.Scope to Correct Root Cause: Replace with higher quality LVDT connectors (current outage).

Additional Scope:


N/A









NERC Cause Code: 1005NERC Cause Code Description: generating tube leaksRoot Cause Description: ID Pitting and erosion of boiler tubes

Event Description: Boiler leak extensionAdditional Description:

Mode of Failure: RH leak in RH pendant (ID Pitting) SH Element erosion failureFinal Corrective Action: Tube replacement of bad sectionsMechanism Causing:Final Root Cause RH/Pitting and SH/ErosionScope to Correct Root Cause: Replace tubing sectionsAdditional Scope:










NERC Cause Code: 1005NERC Cause Code Description: Generating tube leaksRoot Cause Description: One reheater leak was found in loop #6 of the inlet pendants on the north

side, 26th tube from the north. While spreading pendants, found an adjacent leak


Mode of Failure: ID generated oxygenated pitting. Final Corrective Action:Mechanism Causing: Out of service pitting due to condensationFinal Root Cause Insufficient RH drying process.Scope to Correct Root Cause: Replaced affected lower loopAdditional Scope: One leak was also found in the primary superheat lower bank, near the

bottom of the bundle, just above the header. This leak was caused by fly ash erosion.










NERC Cause Code: 3260NERC Cause Code Description: traveling screensRoot Cause Description: Original design allowed fish to pass and the original screen drive was

beyond end of life and worn to the point it continued to fail sprockets/chains and bind.

Event Description: Screen Drive OutageAdditional Description:

Mode of Failure: End of life (components worn causing binding) and poor original design (allowing fish to pass)

Final Corrective Action: Replace with a known and proven style that is reliable for unit operation

Mechanism Causing:Final Root Cause End of life (components worn causing binding) and poor original design

(allowing fish to pass)Scope to Correct Root Cause: Replace entire screen driveAdditional Scope:










NERC Cause Code: 9910NERC Cause Code Description: condensate water pre treatmentRoot Cause Description: Excessive starts used more than expected water

Event Description: DI water shortageAdditional Description:

Mode of Failure: Start up equipment issues used excessive water more than we could produce.

Final Corrective Action: Repaired bad valves and utilized back up valves to correct issueMechanism Causing:Final Root Cause Drum level controlScope to Correct Root Cause: Repaired bad valves and utilized back up valves to correct issueAdditional Scope:










NERC Cause Code: 3300NERC Cause Code Description: condensate water pre treatmentRoot Cause Description: Excessive starts used more than expected water

Event Description: DI water shortageAdditional Description:

Mode of Failure: Start up equipment issues used excessive water more than we could produce.

Final Corrective Action: Repaired bad valves and utilized back up valves to correct issueMechanism Causing:Final Root Cause Drum level controlScope to Correct Root Cause: Repaired bad valves and utilized back up valves to correct issueAdditional Scope:










NERC Cause Code: 1000NERC Cause Code Description: Furnace Wall LeaksRoot Cause Description: The failure was a longitudinal through wall crack roughly 2-3” long. ID

generated underdeposit corrosion cell.

Event Description: Maintenance Outage for Boiler LeakAdditional Description:

Mode of Failure: Pressure boundary failure in waterwall tubingFinal Corrective Action: Replaced damaged tubing with dutchman.Mechanism Causing: Short term overheatFinal Root Cause Under deposit corrosionScope to Correct Root Cause: Replaced damaged tubing with dutchman.Additional Scope:










NERC Cause Code: 4613NERC Cause Code Description: hydrogen seals (NOTE: This leak was not H2 seals, it was doors near them)Root Cause Description: Defective gaskets supplied by OEM

Event Description: Hydrogen leak repairs on turbineAdditional Description:

Mode of Failure: Failed gasketsFinal Corrective Action: Replaced gaskets with upgraded OEM gasketsMechanism Causing: Porous gasket material supplied by OEM.Final Root Cause Gaskets were permiable and H2 gas leaked through the porous area of the

gasketsScope to Correct Root Cause: Remove doors, clean surfaces and replace with newly upgraded material

gaskets provided by OEM.Additional Scope:










NERC Cause Code: 9930NERC Cause Code Description: Operating Procedure Error...Root Cause Description:

Event Description: SF due to 299 metering knife switches not closedAdditional Description:

Mode of Failure:Final Corrective Action:Mechanism Causing:Final Root Cause Procedure errorScope to Correct Root Cause: Corrected procedure to ensure operations knows to close to the knife

switchesAdditional Scope:








Start Date: 4/21/2017 0:00End Date: 5/11/2017 5:25Outage Type: PE


NERC Cause Code: 1510NERC Cause Code Description: flue gas ducts (except recirculation)Root Cause Description: Damper controls were out of alignment

Event Description: Periodic outage extentionAdditional Description:

Mode of Failure: ID Fan Damper issuesFinal Corrective Action: Tuned the dampers to align with each otherMechanism Causing:Final Root Cause Damper controls were out of alignmentScope to Correct Root Cause: Tuned and repaired enough to run the unit.Additional Scope:


Damper binding and alignments had to be performed. Troubleshooting/investigation was performed on the mechanical and electrical side too ensure we didn't have other issues causing the binding. This included inspecting and testing the actuators.









NERC Cause Code: 1510NERC Cause Code Description: flue gas ducts (except recirculation)Root Cause Description: Damper blades cracked

Event Description: Breeching replacement and repair, 3B ID fan repair. BOP work.Additional Description: ID Fan inlet damper blades

Mode of Failure:Final Corrective Action:Mechanism Causing: Fatigue failureFinal Root Cause Fatigue failureScope to Correct Root Cause: Weld repair cracked areas and replaced a few bladesAdditional Scope:










NERC Cause Code: 1510NERC Cause Code Description: flue gas ducts (except recirculation)Root Cause Description: ID Fan Damper issues

Event Description: Periodic outage Additional Description:

Mode of Failure: ID Fan Damper control issuesFinal Corrective Action: Tuned the dampers to align with each other, repaired and cleaned the

system enough to get them to function. Mechanism Causing: The old actuators are not designed very well to run in colder weather, if

your due point is not perfect you can get moisture in system and cause sluggish actuator responses.

Final Root Cause Moisture in the air lines causing sluggish actuator responseScope to Correct Root Cause: Tuned and repaired enough to run the unit. Additional Scope: We are engineering a solution to this probrem which will eliminate the air

lines with the moistures issues. Longer term fix 1-2 years out.


The dampers and controls were not functioning together causing the unit to trip. There were multiple contributors to the issues and we had to methodically troubleshoot one variable at a time. We had moisture issues within the air lines of the actuators casuing them to act sluggish. So each actuator was re-acting at a different rate. This causes the actutors to fight each other and is tough to tune.









NERC Cause Code: 1510NERC Cause Code Description: flue gas ducts (except recirculation)Root Cause Description: Ductwork end of life

Event Description: Breeching replacement and repair, 3B ID fan repair, BOP workAdditional Description:

Mode of Failure: Ductwork past end of life and structurally unsafeFinal Corrective Action: Replaced duct work sections in the highest priority areasMechanism Causing:Final Root Cause Ductwork end of lifeScope to Correct Root Cause: Replace highest priority secton from plant to ID Fan.Additional Scope:









Duration (Hours):MWh Loss:

NERC Cause Code: 3999NERC Cause Code Description: Other Miscellaneous Balance Of Plant Problems...Root Cause Description: Fall outage to prepare for winter months to prevent equipment freezing.

Aux boilers and main regulators were the main scope of work.

Event Description: Plant house heating outageAdditional Description: There were 40 issues repaired on the auxiliary boilers that needed to be

addressed or we would not have reliable winter heating. 4 Main Regulators were repaired too.

Mode of Failure: Winter readiness outageFinal Corrective Action: Repaired aux boilers and main regulators.Mechanism Causing: Age of equipment and increased operating hoursFinal Root CauseScope to Correct Root Cause: Repaired aux boilers and main regulators.Additional Scope:










NERC Cause Code: 4899NERC Cause Code Description: Other Miscellaneous Generator Problems...Root Cause Description: Auxillary relay failure

Event Description: Ongoing reported issues with AVRAdditional Description:

Mode of Failure: Contact on Aux relay not allowing breaker to close properlyFinal Corrective Action: Lubed field breaker and cleaned contactMechanism Causing: Mechanical resistance to breaker actuation.Final Root Cause OEM recommendation for interval maintenance excessive.Scope to Correct Root Cause: increase frequency of PM inspection of field breaker.Additional Scope:










NERC Cause Code: 1510NERC Cause Code Description: flue gas ducts (except recirculation)Root Cause Description: The unit tripped due to furnace draft, which was caused by the erratic

operation of the 3A ID Fan inlet dampers.

Event Description: Breeching replacement and repair, 3B ID fan repair, BOP workAdditional Description: Extensive repairs to ID fan inlet and outlet damper blades performed.

Mode of Failure: Moisture in air lines, caused the inlet damper to move slower than the outlet, in turn the dampers fight each other and swing the boiler pressure until it tripped

Final Corrective Action: Increase dew point and clean and blew out air lines and cleaned the servo valves

Mechanism Causing: Moisture in air linesFinal Root Cause Moisture in air linesScope to Correct Root Cause: Cleaned the air lines out, clean servos, dew point was within specification.

Additional Scope: Engineering is looking at a permenant fix for this issue and that may require an upgrade to get rid of the air control actuators










NERC Cause Code: 1510NERC Cause Code Description: flue gas ducts (except recirculation)Root Cause Description:

Event Description: Periodic Outage ContinuationAdditional Description: Start up balancing of fans

Mode of Failure:Final Corrective Action:Mechanism Causing: High vibrations on 3B ID FanFinal Root Cause ImbalanceScope to Correct Root Cause: Install balance shotAdditional Scope:











Event Description: Periodic Outage ContinuationAdditional Description: tripped on high drum level

Mode of Failure: Control valve stickingFinal Corrective Action:Mechanism Causing: Binding, gummed up valveFinal Root Cause Open/clean/inspect valveScope to Correct Root Cause: Cleaned and inspected valve, then returned to serviceAdditional Scope:











Event Description: Periodic Outage ContinuationAdditional Description:

Mode of Failure: Control valve stickingFinal Corrective Action:Mechanism Causing: Binding, gummed up valveFinal Root Cause Open/clean/inspect valveScope to Correct Root Cause: Cleaned and inspected valve, then returned to serviceAdditional Scope:











Event Description: Periodic Outage ContinuationAdditional Description: Tripped on High drum level again

Mode of Failure: sticking/binding control valveFinal Corrective Action:Mechanism Causing:Final Root Cause sticking/slow responseScope to Correct Root Cause: Readjusted valve and freed it up.Additional Scope: Long lead time valve, this valve needs to be replaced. Notification is in the

planning system.











Event Description: Periodic Outage ContinuationAdditional Description: DCS Control issues

Mode of Failure: Valve cyclingFinal Corrective Action:Mechanism Causing: DCS Card failureFinal Root Cause DCS Card failureScope to Correct Root Cause: Replaced card and recalibratedAdditional Scope:











Event Description: Periodic Outage ContinuationAdditional Description: DCS Control issues

Mode of Failure: Valve cycling, caused over pressure of boilerFinal Corrective Action:Mechanism Causing: DCS Card failureFinal Root Cause DCS Card failureScope to Correct Root Cause: Replaced card and recalibratedAdditional Scope:











Event Description: Periodic Outage ContinuationAdditional Description: Overflowed hotwell due to valve sticking open

Mode of Failure: Valve stickingFinal Corrective Action: repaired valveMechanism Causing:Final Root Cause binding valveScope to Correct Root Cause: Repaired binding valveAdditional Scope:











Event Description: Periodic Outage ContinuationAdditional Description: ID Fan tripped

Mode of Failure: Bearing failedFinal Corrective Action:Mechanism Causing:Final Root Cause One of two potential causes: less than adequate oil flow to bearing, due to

either blockage or it was not aligned properly. Final root cause could actually be determined as this is not instrumented enough to get the data.

Scope to Correct Root Cause: Opened up orifice and balanced bearing oil flows, re-checked rotor alignment to bearings to ensure it was not a loading issue. Issue was resolved ensurig proper oil flow and alignment.

Additional Scope:











Event Description: Periodic Outage ContinuationAdditional Description: Post Maintenance testing of the ID Fan

Mode of Failure:Final Corrective Action:Mechanism Causing:Final Root Cause Post maintenance testing and adjustments to oil flowScope to Correct Root Cause: PMT balanced oil flows one final time.Additional Scope:











Event Description: Periodic Outage ContinuationAdditional Description: Post Maintenance testing of the ID Fan

Mode of Failure:Final Corrective Action:Mechanism Causing:Final Root Cause Post maintenance testing and adjustments to oil flow and balanceScope to Correct Root Cause: PMT added a balance trim shot.Additional Scope:










NERC Cause Code: 1510NERC Cause Code Description: flue gas ducts (except recirculation)Root Cause Description: The unit tripped due to furnace draft, which was caused by the erratic

operation of the 3A ID Fan inlet dampers.

Event Description: Breeching replacement and repair, 3B ID fan repair, BOP workAdditional Description: Extensive repairs to ID fan inlet and outlet damper blades performed.

Mode of Failure: Moisture in air lines, caused the inlet damper to move slower than the outlet, in turn the dampers fight each other and swing the boiler pressure until it tripped

Final Corrective Action: Increase dew point and clean and blew out air lines and cleaned the servo valves

Mechanism Causing: Moisture in air linesFinal Root Cause Moisture in air linesScope to Correct Root Cause: Cleaned the air lines out, clean servos, dew point was within specification.

Additional Scope: Engineering is looking at a permenant fix for this issue and that may require an upgrade to get rid of the air control actuators










NERC Cause Code: 4283NERC Cause Code Description: turbine lube oil system valves and pipingRoot Cause Description: Original bearing design was a poor design and this was a historical issue in

addition to this there was significant runout on exciter stub shaft.

Event Description: Reliability repairsAdditional Description:

Mode of Failure: High vibration on the #8 bearing and the #1 bearingFinal Corrective Action: Realignment of the stub shaft, replaced bearings with newly designed

bearing to dampen the historical vibration issueMechanism Causing:Final Root Cause Original bearing design was a poor design(newer technology resolved the

high vibrations) and this was a historical issue in addition to this there was significant runout on exciter stub shaft.

Scope to Correct Root Cause: Realignment of the stub shaft, replaced bearings with newly designed bearing to dampen the historical vibration issue

Additional Scope:










NERC Cause Code: 4283NERC Cause Code Description: turbine lube oil system valves and pipingRoot Cause Description: Lube oil cooler head was leaking

Event Description: Periodic outage extentionAdditional Description:

Mode of Failure: Lube oil cooler head was leakingFinal Corrective Action: Remove, clean faces and re-torque cooler heads.Mechanism Causing:Final Root Cause Defect in manufacturing of new cooler headsScope to Correct Root Cause: Clean and machine surfaces of the cooler heads.Additional Scope:










NERC Cause Code: 4306NERC Cause Code Description: Automatic Turbine Control Systems -elec-hyd-analog...Root Cause Description: Contamination of fluid by leak.

Event Description: EHC sytem contaminationAdditional Description:

Mode of Failure: FME contamination from faulty EHC door seal allowing debris to enter when a leaking cooler (above) sprayed water onto the EHC tank.

Final Corrective Action: Filtered EHC fluid to remove contaminants. Replaced faulty door seal. Repaired cooler leak.

Mechanism Causing: Faulty door sealFinal Root Cause Foreign material contaminationScope to Correct Root Cause: Filtered EHC fluid to remove contaminants. Replaced faulty door seal.

Repaired cooler leak.Additional Scope:











Event Description: Continuation of Reliability RepairsAdditional Description:











NERC Cause Code: 3245NERC Cause Code Description: Other Cooling Tower Problems…Root Cause Description: Age of wood, past end of expected life.. It is original.

Event Description: Cooling water tower outageAdditional Description:

Mode of Failure: Rotted Cooling tower structural woodFinal Corrective Action: Replace structural wood, fan and water decks on the 6 worst cells.Mechanism Causing: Environment - water/moisture/thermal cyclesFinal Root Cause Age of wood, past end of expected life.. It is original.Scope to Correct Root Cause: Replace cooling tower cells 6 per year, taking the worse condition ones

first to mitigate any safety issues.Additional Scope:










NERC Cause Code: 4290NERC Cause Code Description: Turbine Hydraulic System PumpsRoot Cause Description: pinched oring due to misaligned flange







Page: 85of 128Witness: DBKehoeDate: March 2018













Sequence Number: Ludington Unit 1-2017-1Plant/Unit: Ludington Unit 1MW Derate:




NERC Cause Code: 7201NERC Cause Code Description: Hydro/pump Storage InspectionRoot Cause Description: Planned Inspection Activity

Event Description: Unit #1 Planned 2-year Inspection OutageAdditional Description:

Mode of Failure: No failure, planned maintenance.Final Corrective Action: N/AMechanism Causing: N/AFinal Root Cause N/AScope to Correct Root Cause: N/AAdditional Scope: N/A



INFORMATION FOR UNIT - Ludington Unit 1PERIODIC OUTAGE








Event Description: Unit #1 Planned 2-year Inspection Outage (after testing)Additional Description:












Event Description: Unit #1 Planned 2-year Inspection Outage (after testing)Additional Description:



Post outage maintenance testing and filter cleaning.









NERC Cause Code: 7007NERC Cause Code Description: Hydro/pump storage - turbine bearingsRoot Cause Description: Planned Outage Activity

Event Description: Unit #2 Planned Outage - Turbine Guide Bearing ModificationAdditional Description:

Mode of Failure: Inability to pump turbine into high resovoir levels (Net Head) due to excessive turbine shaft vibration.

Final Corrective Action: Replacement of the turbine guide bearings with new bearings with a larger radius and enhanced dampening ability.

Mechanism Causing: Unforeseen hydralic self excitation on new turbine prototype.Final Root Cause Unintended consequence of discharge ring seal configuration.Scope to Correct Root Cause: Replacement of the turbine guide bearing shoes and colateral cleaning of

the turbine guide bearing tub of foreign material. Additional Scope: N/A












Mode of Failure: N/AFinal Corrective Action: N/AMechanism Causing: Testing / troubleshooting subsiquent to Turbine Guide bearing Outage

Event 93Final Root Cause N/AScope to Correct Root Cause: N/AAdditional Scope: N/A












Mode of Failure: N/AFinal Corrective Action: N/AMechanism Causing: Testing / troubleshooting subsiquent to Turbine Guide bearing Outage Event

93Final Root Cause N/AScope to Correct Root Cause: N/AAdditional Scope: N/A










NERC Cause Code: 7200NERC Cause Code Description: major hydro/pump storage overhaulRoot Cause Description: No failure - this was a planned outage.

Event Description: Major Overhauld (MOH) unit 5Additional Description:











NERC Cause Code: 7200NERC Cause Code Description: major hydro/pump storage overhaulRoot Cause Description: Not an equipment failure

Event Description: MOH unit 5Additional Description:

Mode of Failure: N/AFinal Corrective Action: N/AMechanism Causing: N/AFinal Root Cause N/AScope to Correct Root Cause: N/AAdditional Scope: Base scope


Best estimate of outage duration was submitted prior to completion of the LPS 4 outage. Scope was known, duration was longer than expected due to contractor scheduling and management of their subcontractors.









NERC Cause Code: 3620NERC Cause Code Description: Main TransformerRoot Cause Description: Planned Inspection Activity

Event Description: Main Transformer Bank (MTB) #3 outage-GSU replacementAdditional Description: Unit 5 and Unit 6 at LPS share a transformer bank. For overall plant

reliability, the transformers were replaced prior to the second overhauled unit coming online. This outage was necessary to allow full replacement of the end of service life transformers.












Event Description: Main Transformer Bank (MTB) #3 outage-GSU replacement testingAdditional Description: Replacement of relays to support MTB replacement outages.



Delay in working clearance tag removal resulted in returing the unit to service 0.65 hours later than scheduled.









NERC Cause Code: 7200NERC Cause Code Description: major hydro/pump storage overhaulRoot Cause Description:

Event Description: MOH - Load Rejection TestingAdditional Description:

Mode of Failure: N/AFinal Corrective Action: N/AMechanism Causing: Contractual and OEM required commissioning test prior to unit interim

acceptance (6/6/2017)Final Root Cause N/AScope to Correct Root Cause: N/AAdditional Scope: N/A











Event Description: MOH - Pump TestingAdditional Description:













Event Description: MOH - TestingAdditional Description:












NERC Cause Code: 7200NERC Cause Code Description: major hydro/pump storage overhaulRoot Cause Description: N/A

Event Description: MOH unit 6Additional Description: Execution of the LPS Unit 6 major overhaul.







Sequence Number: Straits-2017-1Plant/Unit: Straits 1MW Derate: 10




NERC Cause Code: 5109NERC Cause Code Description: Other Gas Turbine Exhaust Problems...Root Cause Description: Fatigue

Event Description: Broken Exhaust Duct FlangeAdditional Description: Unit tripped (start failure occurred) due on high compartment temperature

Mode of Failure: Metal Embrittlement / CrackingFinal Corrective Action: Replace Exhaust DuctMechanism Causing: Thermal CyclingFinal Root Cause FatigueScope to Correct Root Cause: Repaired existing duct (no replacement available)Additional Scope:



INFORMATION FOR UNIT - Straits Unit 1PERIODIC OUTAGE



Sequence Number: Allegan unit 1-2017-1Plant/Unit: Allegan unit 1MW Derate:




NERC Cause Code: 3644NERC Cause Code Description: Protective devicesRoot Cause Description: The turbine runner was found to have large cracks at the blade root. The

runner is original from 1935 and the cracks grew large enough to cause the turbine to become unstable.

Event Description: Noise - Lower Guide Bearing issueAdditional Description:

Mode of Failure: Turbine runner blade fatigueFinal Corrective Action: Engineering has welded up the cracks and is in the process of refurbishing

the thrust and guide bearingsMechanism Causing: Turbine runner blade fatigueFinal Root Cause The construction of the runner made the blades prone to cracking.

Scope to Correct Root Cause: The runner has been rewelded to the hub in the areas of crackingAdditional Scope: Engineering is in the process of refurbishing the thrust and guide bearings


No outage extention for an Unplanned outage


INFORMATION FOR UNIT - Allegan unit 1PERIODIC OUTAGE



Sequence Number: Croton Unit 1-2017-1Plant/Unit: Croton Unit 1MW Derate:




NERC Cause Code: 3644NERC Cause Code Description: Protective devicesRoot Cause Description: Planned Reliability Work

Event Description: Electrical upgradeAdditional Description: The project involved several modifications including, Unit 3 booster

transformer replacement, replacement of the generator disconnects, replacement of the AC and DC distribution system, replacement of the Unit control panels. These modifications resolved safety concerns by updating equipment installed in 1907.

Mode of Failure: No failure was involvedFinal Corrective Action: The project and modifications were completedMechanism Causing: Old age of original equipmentFinal Root Cause Old age of original equipmentScope to Correct Root Cause: Unit 3 booster transformer replaced, generator disconnects replaced, AC

and DC distribution systems replaced, Unit control panels replaced.

Additional Scope: Lightning arrestors and some faulty cabling discovered and replaced


Lightning arrestors and some faulty cabling discovered and replaced to eliminate a safety hazard and improve reliability


INFORMATION FOR UNIT - Croton unit 1PERIODIC OUTAGE







NERC Cause Code: 3644NERC Cause Code Description: Protective devicesRoot Cause Description: Lightning arrestors compromised.

Event Description: Electrical upgrade extendedAdditional Description: This was a periodic extension to complete the Electrical Safety Project

work scope.














NERC Cause Code: 7007NERC Cause Code Description: Hydro/pump Storage - Turbine Bearings...Root Cause Description: The turbine bearings wear and require regular adjustments by design

Event Description: Noise from Turbine BearingAdditional Description: The turbine bearings became worn and the runner came in contact with

the housing.

Mode of Failure: Wear on the turbine bearingsFinal Corrective Action: Adjusted the turbine bearingsMechanism Causing: Normal WearFinal Root Cause The turbine bearings wear and require regular adjustments by design

Scope to Correct Root Cause: Made adjustments to the turbine bearingsAdditional Scope: Completed all turbine pit work scheduled later in the year


No extension, this was a forced outage.









NERC Cause Code: 3644NERC Cause Code Description: Protective devicesRoot Cause Description: Planned Reliability Work

Event Description: Electrical upgradeAdditional Description: The project involved several modifications including, Unit 3 booster

transformer replacement, replacement of the generator disconnects, replacement of the AC and DC distribution system, replacement of the Unit control panels. These modifications resolved safety concerns by updating equipment installed in 1907.














NERC Cause Code: 3644NERC Cause Code Description: Protective devicesRoot Cause Description: Lightning arrestors compromised.

Event Description: Electrical outage exendedAdditional Description: This was a periodic extension to complete the Electrical Safety Project

work scope.














NERC Cause Code: 3644NERC Cause Code Description: Protective devicesRoot Cause Description: The outage initially started due to the failure of the Unit 4 bearings and

transitioned into the Planned Outage for the Electrical Safety Project. Unit 3 and 4 have a shared penstock so Unit3 had to be removed from service to troubleshoot the Unit 4 bearing failure.

Event Description: Unit swing due to unit #4 issueAdditional Description: The outage initially started due to the failure of the Unit 4 bearings and

transitioned into the Planned Outage for the Electrical Safety Project. Unit 3 and 4 have a shared penstock so Unit3 had to be removed from service to troubleshoot the Unit 4 bearing failure.

Mode of Failure: Failed bearing on Unit 4Final Corrective Action: The project and modifications were completed, Unit 4 was stabilized so the

shared penstock could be flooded and Unit 3 made available.

Mechanism Causing: Old age of original equipmentFinal Root Cause Old age of original equipment





Scope to Correct Root Cause: Unit 3 booster transformer replaced, generator disconnects replaced, AC and DC distribution systems replaced, Unit control panels replaced.



Lightning arrestors and some faulty cabling discovered and replaced to eliminate a safety hazard and improve reliability. The Unit 3 booster transformer was manufactured incorrectly and failed causing the majority of the additional delay.







NERC Cause Code: 3644NERC Cause Code Description: Protective devicesRoot Cause Description: The turbine guide bearing failed from old age and poor condition

Event Description: Losing bearing pressureAdditional Description: The outage initially started due to the failure of the Unit 4 bearings. The

planned Electrical Safety Project was completed during this outage. The unit will remain out of service until funding can be allocated for its repair.

Mode of Failure: Failed bearing Final Corrective Action: The unit has not been repaired yet.Mechanism Causing: Old age of original equipmentFinal Root Cause Old age of original equipmentScope to Correct Root Cause: Engineering is underway to determine the repair scope.Additional Scope: The Electrical Safety Project was completed during this unplanned outage


No extension for and unplanned outage





Sequence Number: Foote unit 2-2017-1Plant/Unit: Foote unit 2MW Derate:




NERC Cause Code: 7007NERC Cause Code Description: Hydro/pump storage-turbine bearingsRoot Cause Description: Lower steady bearing bolts backed out allowing lower steady bearing to

shift cutting off oil flow. The lower steady bearing bolts have been in place likely for decades and it is unknown why they backed out.

Event Description: Lower steady bearing wear due to loss of oilAdditional Description:

Mode of Failure: Loss of lubrication to lower steady bearingFinal Corrective Action: Refurbished turbine guide bearing, steady bearings and thrust bearing.

Mechanism Causing: Bearing surface wearFinal Root Cause Lower steady bearing bolts backed out.Scope to Correct Root Cause: Refurbished turbine guide bearing, steady bearings and thrust bearing.

Additional Scope: None


No extension to an Unplanned outage


INFORMATION FOR UNIT - Foote unit 2PERIODIC OUTAGE



Sequence Number: Foote unit 2-2017-2Plant/Unit: Foote unit 2MW Derate:




NERC Cause Code: 3644NERC Cause Code Description: Protective devicesRoot Cause Description:

Event Description: Field Switch Forced OutageAdditional Description: Coil failed to deenergize when Breaker closed and burnt up the coil and

wiring.

Mode of Failure: Energizing coil burnt upFinal Corrective Action: Breaker was refurbished with new coil and wiring.Mechanism Causing: Failed to mechanically disengageFinal Root Cause Decades old equipment coil failed to deenergizeScope to Correct Root Cause: Breaker was refurbished with all new partsAdditional Scope: N/A


N/A


INFORMATION FOR UNIT - Foote unit 2PERIODIC OUTAGE



Sequence Number: Hardy unit 3-2017-1Plant/Unit: Hardy unit 3MW Derate:




NERC Cause Code: 3644NERC Cause Code Description: Protective devicesRoot Cause Description: High flows through a 86 year old spill tube caused the steel liner to

separate from the concrete and tear loose in some places.

Event Description: Spill tube re-liningAdditional Description:

Mode of Failure: Spill tube steel liner failedFinal Corrective Action: The steel spill tube liner was replaced and anchored into concrete.

Mechanism Causing: High flows through the spill tube casued cavitation causing the liner to fail.

Final Root Cause High flows through the spill tube casued cavitation causing the liner to fail.

Scope to Correct Root Cause: The steel spill tube liner was replaced and anchored into concrete.

Additional Scope:


The work took longer than estimates to complete


INFORMATION FOR UNIT - Hardy unit 3PERIODIC OUTAGE














Additional Scope:


The work took longer than estimates to complete
















Additional Scope:


The work took longer than estimated to complete. No extra work was completed same planned work just took longer than expected.





Sequence Number: Hodenpy unit 1-2017-1Plant/Unit: Hodenpy unit 1MW Derate:




NERC Cause Code: 3644NERC Cause Code Description: Protective devicesRoot Cause Description: A governor oil pump developed a leak due to a failure of a bushing set

screw allowing the shaft bushing to move causing the oil leak.

Event Description: A governor oil pump bushing developed a leak at the shaft bushing, the unit was brought down and the pump was sent out to a machine shop for repair.

Additional Description:

Mode of Failure: Bushing wear Final Corrective Action: The governor oil pump was sent for repair and was reinstalled.Mechanism Causing: Set screw failureFinal Root Cause A governor oil pump developed a leak due to a failure of a bushing set

screw allowing the shaft bushing to move causing the oil leak.

Scope to Correct Root Cause: The unit was brought down and the pump was sent out to a machine shop for repair.

Additional Scope: None


No additional work was performed.


INFORMATION FOR UNIT - Mio unit 1PERIODIC OUTAGE



Sequence Number: Mio unit 1-2017-1Plant/Unit: Mio unit 1MW Derate:




NERC Cause Code: 3644NERC Cause Code Description: Protective devicesRoot Cause Description: The upper steady bearing failed causing the unit to trip on high oil

temperature

Event Description: High steady bearing temperature tripAdditional Description:

Mode of Failure: Bearing surface wearFinal Corrective Action: Repairs are in progress, bearings have been sent to vendor for

refurbishmentMechanism Causing: Bearing surface wearFinal Root Cause The cause of the bearing failure could not be determinedScope to Correct Root Cause: Repairs are in progress, bearings have been sent to vendor for

refurbishment, checked oil flow which appears to be fine.Additional Scope:


No extension to an Unplanned outage


INFORMATION FOR UNIT - Mio unit 1PERIODIC OUTAGE



Sequence Number: Rogers unit 1-2017-1Plant/Unit: Rogers unit 1MW Derate:




NERC Cause Code: 3644NERC Cause Code Description: Protective devicesRoot Cause Description: Thrust Bearing Failure

Event Description: Failed thrust bearingAdditional Description: The thrust bearing failed causing the unit to trip on high bearing

temperature.

Mode of Failure: Bearing surface failureFinal Corrective Action: Refurbished the entire unit replacing the thrust bearing with a modern

design, refurbishing the steady and guide bearings, refurbishing the wicket gates and cleaning the generator.

Mechanism Causing:Final Root Cause The original bearing design installed in 1922 is poor and prone to failure

Scope to Correct Root Cause: Replaced the thrust bearing with a modern designAdditional Scope: Refurbished the entire unit replacing the thrust bearing with a modern

design, refurbishing the steady and guide bearings and refurbishing the wicket gates.




INFORMATION FOR UNIT - Rogers unit 1PERIODIC OUTAGE







NERC Cause Code: 7007NERC Cause Code Description: Hydro/pump storage - turbine bearingsRoot Cause Description: Thrust Bearing Failure

Event Description: Failed thrust bearingAdditional Description: The thrust bearing failed causing the unit to trip on high bearing

temperature.

Mode of Failure: Bearing surface failureFinal Corrective Action: Refurbished the entire unit replacing the thrust bearing with a modern


Mechanism Causing:Final Root Cause The original bearing design installed in 1922 is poor and prone to failure

Scope to Correct Root Cause: Replaced the thrust bearing with a modern designAdditional Scope: Refurbished the entire unit replacing the thrust bearing with a modern












NERC Cause Code: 7141NERC Cause Code Description: Wicket gate operating mechanism or positionerRoot Cause Description: Excessive wear on wicket gate linkages and bushings causing binding

Event Description: wicket gate bindingAdditional Description:

Mode of Failure: wicket gate bindingFinal Corrective Action: Engineering is in progress to make repairs to the wicket gates and linkage

bushings in 2017.Mechanism Causing: Worn wicket gate bushings and linkages.Final Root Cause The wicket gate linkages and bushings are extremely worn causing binding

Scope to Correct Root Cause: Engineering is in progress to make repairs to the wicket gates and linkage bushings in 2017.

Additional Scope: Wicket gate replacements are planned to be completed





MICHIGAN PUBLIC SERVICE COMMISSION Case No.: U-20068 Exhibit No.: A-6 (DBK-4)

Consumers Energy Company Page: 1 of 1 Witness: DBKehoe Date: March 2018

2017 FOSSIL AND PUMPED STORAGE OUTAGES OCCURRING FOR TWENTY-EIGHT DAYS OR MORE

Line Unit (a)

Planned Days in 2017 (b)

Actual Days in 2017 (c)

Event Number (d)

1 Ludington 5 104 144 1-10, 12-13

2 Ludington 1 35 39 2, 32, 21

3 Ludington 6 291 279 143-145

4 Karn 3 30 Did not take place NA

5 Karn 4 30 92 52

6 Campbell 1 — 29 34

7 Campbell 1 — 48 112

8 Karn 1 — 28 23, 25

9 Karn 2 — 66 239

10 Karn 3 — 157 1-20

11 Karn 3 — 40 58

12 Karn 4 — 173 1-18

13 Ludington 2 — 35 93-95, 105

14 Ludington 5 — 63 146-148

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MICHIGAN PUBLIC SERVICE COMMISSION Case No.: U-20068 Exhibit No.: A-7 (DBK-5) Consumers Energy Company Page: 1 of 1 Witness: DBKehoe Date: March 2018

GENERATION PERFORMANCE STATISTICS JANUARY 1, 2017 TO DECEMBER 31, 2017

Line

Unit (a)

Unit Avail

(b)

MWh Avail

(c)

Periodic Factor

(d)

Random Outage Rate (e)

1

Campbell 1 73.01% 71.26% 13.58% 17.54%

2

Campbell 2 73.51% 60.89% 12.45% 30.45%

3

Campbell 3 (CE) 92.82% 91.64% 0.03% 8.34%

4

Karn 1 83.13% 73.63% 11.17% 17.11%

5

Karn 2 67.39% 60.33% 24.65% 19.93%

6

Karn 3 41.39% 41.14% 43.15% 27.63%

7

Karn 4 25.65% 24.72% 68.29% 22.04%

8 Zeeland Combined Cycle 93.45% 92.96% 6.02% 1.09%

9 Jackson CC 95.55% 92.17% 4.87% 3.11%

10

Total Fossil CE1 86.28% 82.32% 7.73% 10.78%

11

Base Load Fossil CE 81.70% 76.42% 9.05% 15.98%

12

Total Peakers2 96.17% 96.05% 1.72% 2.61%

13 Ludington 1-6 68.17% 68.17% 30.28% 2.22%

14

Total Hydro 84.45% 84.11% 9.64% 6.92%

1 Does not include Karn 3 and Karn 4. 2 CT’s w/Zeeland 1A & 1B.

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Case No.: U-20068Exhibit No.: A-8 (DBK-6)

Page: 1 of 1Witness: DBKehoeDate: March 2018MICHIGAN PUBLIC SERVICE COMMISSION

Consumers Energy Company

COMPARISON OF CONSUMERS ENERGY AND GADS AVERAGES FOR SIMILAR UNITSEQUIVALENT AVAILABILITY

UNIT CE VERSUS2012-2016 2016 2013-2017 2017 GADS **

CAMPBELL 1 78.59% 79.10% 80.36% 71.26% HigherCAMPBELL 2 80.81% 76.79% 73.66% 60.89% LowerCAMPBELL 3 81.19% 80.74% 81.58% 91.64% HigherKARN 1 78.59% 79.10% 59.16% 73.63% LowerKARN 2 78.59% 79.10% 66.67% 60.33% Lower

** Higher indicates one-year or five-year were higher than the GADs average. Lower indicates both tests were lower than the GADS average.

Indicates unit was off line since May 2016Indicates unit was off line since April 2016

GADS AVERAGES CONSUMERS ENERGY

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Case No.: U-20068Exhibit No.: A-9 (DBK-7)


2017 Base Load Generation Power Plant Cost Efficiency

Ferc form 1 data

GADS Perf measure

report

GADS Perf measure

reportGADS Gen Sum report

GADS Gen Sum report

Heat On-line Planned UnplannedRate Hours Outage Outage Gross MWh Net MWh

Line Plant BTU/kWh Hours Factor Factor Generated Delivered(a) (b) (c) (d) (e) (f) (g)

1 Campbell 1 10,865 5,516 13.58% 13.41% 1,068,621 985,4032 Campbell 2 10,664 5,345 0.00% 26.49% 1,284,947 1,177,0953 Campbell 3 10,032 8,123 0.00% 7.18% 6,219,489 5,836,856

4 Karn 1 10,240 7,178 3.68% 13.18% 1,528,438 1,379,5295 Karn 2 10,311 5,850 18.21% 14.40% 1,283,990 1,156,129

MICHIGAN PUBLIC SERVICE COMMISSION

Consumers Energy Company

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MICHIGAN PUBLIC SERVICE COMMISSION Case No.: U-20068Consumers Energy Company Exhibit No.: A-10 (SJN-1)

Page: 1 of 1Witness: SJNadeauDate: March 2018

LinePlan*

Burn Volumes(b)

Plan* Cost(c)

ActualBurn Volumes

(d)Actual Cost

(e)1 Gas & Oil Units (MCF/bbls)2 Karn 3-4 (Gas) 821,243 9,186,594 $ 1,934,779 12,661,926 $ 3 Karn 3-4 (Oil) 34 1,183 $ 36,335 1,243,938 $ 4 Jackson (Gas) 16,754,130 66,533,623 $ 14,671,955 52,410,475 $ 5 Zeeland (Gas) 26,699,355 99,181,325 $ 22,513,545 74,197,368 $ 6 Total Gas & Oil (lines 2-5): --- 174,902,725 $ --- 140,513,707 $

7 Peaking Units (MCF/bbls)8 Campbell (Oil) 0 0 $ 846 60,292 $ 9 Gaylord (Gas) 0 811,913 $ 25,587 720,521 $

10 Morrow (Gas) 0 0 $ 0 1,264 $ 11 Straits (Gas) 0 207,060 $ 1,542 155,857 $ 12 Thetford (Gas) 0 9,877 $ 6,471 45,001 $ 13 Total Peaking (lines 8-12): --- 1,028,850 $ --- 982,935 $

14 Total Gas & Oil Generation (lines 6, 13): --- 175,931,575$ --- 141,496,641 $

emissions fees.

Plant(a)

Comparison of 2017 As-Burned Costs of Oil & Gas

* 2017 PSCR Plan Case U-18142 as supplemented. Projected costs include auxiliary fuel costs and state air

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MICHIGAN PUBLIC SERVICE COMMISSION Case No.: U-20068Consumers Energy Company Exhibit No.: A-11 (HLP-1)

Page: 1 of 1Witness: HLPattonDate: March 2018

January February March April May June July August September October November December Total(kWh) (a) (b) (c) (d) (e) (f) (g) (h) (i) (j) (k) (l) (m) (n)1. Cycle Billed PSCR Sales (a) 2,951,229,115 2,725,891,200 2,548,505,932 2,553,303,186 2,460,409,894 2,735,029,952 2,954,175,092 3,015,091,792 2,829,046,210 2,696,065,639 2,530,098,338 2,758,352,333 32,757,198,6832. Current Month Unbilled PSCR Sales 1,625,207,325 1,443,297,300 1,670,357,762 1,541,381,017 1,683,457,587 1,855,202,430 2,046,177,166 2,012,756,116 1,937,053,756 1,832,907,023 1,919,189,021 2,102,658,297 21,669,644,8003. Prior Month Unbilled PSCR Sales (1,666,396,042) (1,625,207,325) (1,443,297,300) (1,670,357,762) (1,541,381,017) (1,683,457,587) (1,855,202,430) (2,046,177,166) (2,012,756,116) (1,937,053,756) (1,832,907,023) (1,919,189,021) (21,233,382,545)4. Total Calendar PSCR Sales (Sum of Lines 1 through 3) 2,910,040,398 2,543,981,175 2,775,566,394 2,424,326,441 2,602,486,464 2,906,774,795 3,145,149,828 2,981,670,742 2,753,343,850 2,591,918,906 2,616,380,336 2,941,821,609 33,193,460,938 5. Total Calendar Sales 2,945,347,757 2,576,143,045 2,798,138,533 2,458,759,780 2,640,902,889 2,939,634,753 3,178,922,429 3,024,866,207 2,792,838,033 2,629,928,622 2,648,862,833 2,979,534,145 33,613,879,0266. Interruptible Wholesale and GSG-2 sales (b) 5,548,795 3,585,492 3,883,104 7,659,520 6,814,674 6,715,234 8,861,288 13,715,032 10,953,191 9,030,231 9,759,023 12,580,867 99,106,4517. Total Sales Less Interruptible Wholesale and GSG-2 2,939,798,962 2,572,557,553 2,794,255,429 2,451,100,260 2,634,088,215 2,932,919,519 3,170,061,141 3,011,151,175 2,781,884,842 2,620,898,391 2,639,103,810 2,966,953,278 33,514,772,5758. Percentage PSCR Sales to Net of Incremental Total 98.99% 98.89% 99.33% 98.91% 98.80% 99.11% 99.21% 99.02% 98.97% 98.89% 99.14% 99.15%

(Fuel Factor in Dollars per kWh)9. Base Recovery Factor 0.06011 0.06011 0.06011 0.06011 0.06011 0.06011 0.06011 0.06011 0.06011 0.06011 0.06011 0.06011 10. Billed PSCR Factor (c) (0.00105) (0.00032) (0.00061) (0.00195) (0.00158) (0.00035) (0.00083) (0.00256) (0.00378) (0.00478) (0.00634) (0.00453) 11. Current Month Unbilled PSCR Factor (c) (0.00032) (0.00061) (0.00195) (0.00158) (0.00035) (0.00083) (0.00256) (0.00378) (0.00478) (0.00634) (0.00453) (0.00024) 12. Prior Month Unbilled PSCR Factor (c) (0.00105) (0.00032) (0.00061) (0.00195) (0.00158) (0.00035) (0.00083) (0.00256) (0.00378) (0.00478) (0.00634) (0.00453)

(Dollars)13. Billed PSCR (Line 1*(Line 9 + Line 10)) 174,299,592 162,981,035 151,636,103 148,500,113 144,007,791 163,445,390 175,123,499 173,518,533 159,360,173 149,173,312 136,043,388 153,309,223 1,891,398,15114. Current Month Unbilled PSCR (Line 2*(Line 9 + Line 11)) 97,171,146 85,876,189 97,148,007 90,217,031 100,603,425 109,976,400 117,757,496 113,378,552 107,177,184 98,555,411 106,668,526 125,886,152 1,250,415,52015. Prior Month Unbilled PSCR (Line 3*(Line 9 + Line 12)) (98,417,350) (97,171,146) (85,876,189) (97,148,007) (90,217,031) (100,603,425) (109,976,400) (117,757,496) (113,378,552) (107,177,184) (98,555,411) (106,668,526) (1,222,946,718)16. Total PSCR Revenue 173,053,387 151,686,078 162,907,921 141,569,137 154,394,186 172,818,365 182,904,595 169,139,589 153,158,805 140,551,538 144,156,503 172,526,849 1,918,866,953

(Power Supply Cost)17. Fuel for Generation (d) 32,623,765 22,595,718 31,134,729 26,524,683 33,415,611 36,924,259 40,321,349 36,268,701 35,688,971 30,958,614 27,217,692 33,426,714 387,100,80618. Purchased and Interchange Power (e) 105,217,378 118,378,910 117,432,792 113,380,116 124,794,253 137,731,104 150,673,007 149,662,793 140,244,867 123,203,043 120,506,458 128,918,133 1,530,142,85419. Environmental Costs (f) 640,882 922,434 994,489 898,643 1,014,954 288,156 1,193,858 961,794 850,479 898,520 800,641 603,153 10,068,00320. Total Costs (Sum of Lines 17 through 19) 138,482,025 141,897,062 149,562,010 140,803,442 159,224,818 174,943,519 192,188,214 186,893,288 176,784,317 155,060,177 148,524,791 162,948,000 1,927,311,66321. Less Costs of Interruptible Wholesale/GSG-2 Sales 235,639 146,902 161,449 264,210 271,949 251,051 458,148 1,034,991 670,238 476,437 352,056 473,034 4,796,10422. Total Costs Less Incremental Costs (Line 20 - Line 21) 138,246,386 141,750,160 149,400,561 140,539,232 158,952,869 174,692,468 191,730,066 185,858,297 176,114,079 154,583,740 148,172,735 162,474,966 1,922,515,55923. Jurisdictional Percentage 98.99% 98.89% 99.33% 98.91% 98.80% 99.11% 99.21417% 99.02% 98.97% 98.89% 99.14% 99.15%24. Total Cost Allocated to PSCR (Line 22 * Line 23) 136,846,966 140,175,577 148,401,314 139,004,096 157,045,876 173,135,219 190,223,392 184,038,666 174,307,221 152,874,495 146,896,923 161,098,717 1,904,048,462

25. Current Year Over/(Under) Recovery (Line 16 - Line 24) 36,206,421 11,510,502 14,506,607 2,565,041 (2,651,690) (316,854) (7,318,797) (14,899,078) (21,148,416) (12,322,957) (2,740,421) 11,428,132 14,818,491

26. Prior Year Over/(Under) Recovery (g) 11,766,792 11,766,792

27. Cumulative Over/(Under) Recovery 47,973,213 59,483,715 73,990,322 76,555,363 73,903,673 73,586,819 66,268,022 51,368,944 30,220,528 17,897,571 15,157,151 26,585,283 26,585,283

(a) Provided by Customer Billing System(b) Interruptible Wholesale Sales and GSG-2 Sales(c) Monthly PSCR factor letters filed with MPSC (d) Provided by Company witness Nadeau(e) Provided by company witness Ronk(f) Provided by company witness Schram(g) From U-17918-R Gretchen Wagner (S-1-R)

Consumers Energy Company2017 Power Supply Cost Recovery Reconciliation

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MICHIGAN PUBLIC SERVICE COMMISSION Consumers Energy Company Case No.: U-20068Consumers Energy Company PSCR Interest Calculation 2017 Exhibit No.: A-12 (HLP-2)

Page: 1 of 1Witness: HLPattonDate: March 2018

Prior Month Cumulative Current Month InterestMonth Over/(Under) Recovery Over/(Under) Recovery O/(U) for Interest Interest Rate (Income)/Expense

(a) (b) (c) (d) (e) (f)1. January 11,766,792 36,206,421 29,870,003 0.0086 256,3842. February 47,973,213 11,510,502 53,728,464 0.0086 461,1693. March 59,483,715 14,506,607 66,737,019 0.0084 563,8564. April 73,990,322 2,565,041 75,272,843 0.0084 633,5465. May 76,555,363 (2,651,690) 75,229,518 0.0084 633,1826. June 73,903,673 (316,854) 73,745,246 0.0084 620,6897. July 73,586,819 (7,318,797) 69,927,420 0.0084 588,5568. August 66,268,022 (14,899,078) 58,818,483 0.0084 495,0569. September 51,368,944 (21,148,416) 40,794,736 0.0084 343,35610. October 30,220,528 (12,322,957) 24,059,050 0.0084 202,49711. November 17,897,571 (2,740,421) 16,527,361 0.0084 139,10512. December 15,157,151 11,428,132 20,871,217 0.0084 175,66613. 14,818,491 5,113,062

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MICHIGAN PUBLIC SERVICE COMMISSION Case No.: U-20068Consumers Energy Company Exhibit No.: A-13 (AKR-1)

Page: 1 of 1Witness: AKRissmanDate: March 2018

Line Contract IDContract Start

Date Contract End DatePlan Volume

(Tons)Actual Received Volume (Tons) Variation from Plan (Tons)

(a) (b) (c) (d) (e) (f)

1 Western Contract Receipts2 173 1/1/2016 12/31/2017 1,422,720 1,427,989 5,269 3 193 1/1/2016 12/31/2018 1,497,600 1,460,570 (37,030) 4 220 1/1/2017 12/31/2017 180,000 190,595 10,595 5 221 1/1/2017 12/31/2017 187,200 190,398 3,198 6 222 1/1/2017 12/31/2017 187,200 190,614 3,414 7 223 1/1/2017 12/31/2017 374,400 366,494 (7,906) 8 232 1/1/2017 12/31/2017 60,000 507,651 447,651 9 234 1/1/2017 12/31/2018 561,000 587,647 26,647

10 243 1/1/2017 12/31/2018 0 571,711 571,711 11 160 0 110,854 110,854 12 165 0 79,242 79,242 13 173 0 126,574 126,574 14 (New) N/A N/A 1,564,310 0 (1,564,310) 15 Total Western Contract Receipts (lines 2-14): 6,034,430 5,810,339 (224,091)

16 Western Spot Receipts17 173S 10/1/2017 12/31/2017 0 242,125 242,125 18 284 10/1/2017 12/31/2017 0 79,376 79,376 19 248 1/1/2017 3/31/2017 0 413,799 413,799 20 (New) N/A N/A 1,000,000 0 (1,000,000) 21 Total Western Spot Receipts (lines 17-20): 1,000,000 735,300 (264,700)

22 Total Western Receipts (lines 15,21): 7,034,430 6,545,639 (488,791)

23 Eastern Contract Receipts24 (New) N/A N/A 0 0 - 25 Total Eastern Contract Receipts (line 24): - - -

26 Eastern Spot Receipts27 265 1/1/2017 1/31/2017 0 10,235 10,235 28 285 1/1/2017 4/30/2017 0 607 607 29 277 4/1/2017 4/30/2017 0 11,900 11,900 30 240 0 1,540 1,540 31 239 0 11,790 11,790 32 267 2/1/2017 2/28/2017 0 11,766 11,766 33 (New) N/A N/A 0 0 - 34 Total Eastern Spot Receipts (lines 27-33): 0 47,839 47,839

35 Total Eastern Receipts (line 25,34): - 47,839 47,839

36 Total Coal Receipts (lines 22,35): 7,034,430 6,593,478 (440,952)

2017 Coal Receipts - Plan and Actual

2016 Commitment2016 Commitment

2016 Commitment

2016 Commitment2016 Commitment

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MICHIGAN PUBLIC SERVICE COMMISSION Case No.: U-20068Consumers Energy Company Exhibit No.: A-14 (AKR-2)

Page: 1 of 1Witness: AKRissmanDate: March 2018

LinePlan

Burn Volumes(b)

Plan Cost(c)

ActualBurn Volumes

(d)Actual Cost

(e)1 Coal Units (Tons)

2 Campbell 1-2 2,015,755 89,210,548 $ 1,303,777 57,301,722 $ 3 Campbell 3 3,178,562 140,071,322 $ 3,031,230 130,877,086 $ 4 Karn 1-2 1,734,473 67,773,283 $ 1,481,296 57,425,357 $ 5 Total Coal (lines 2-4): 6,928,790 297,055,153 $ 5,816,303 245,604,165 $

6 Total Expenditures: 245,604,165 $

Comparison of 2017 As-Burned Cost of Fuel

Plant(a)

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MICHIGAN PUBLIC SERVICE COMMISSION Case No.: U-20068Consumers Energy Company Exhibit No.: A-15 (RTS-1)

Page: 1 of 1Witness: RTScaifeDate: March 2018

Line Year Charge Description1 2017 MISO Financial Transmission and Auction Revenue Rights ($10,353,066.21)2 2017 Schedule 16 - Financial Transmission Rights Administration Service Cost $114,939.603 2017 Schedule 24 - Local Balancing Authority Cost Recovery $843,606.354 2017 MISO Energy Market Purchases and Sales $132,166,584.225 2017 Schedule 17 - Energy Market Support Administration Service Cost $5,676,630.346 2017 MISO Ancillary Service Market Transactions ($1,795,958.93)

7 Total Settlement of MISO Market and Tariff Administration Charges/(Credits) $126,652,735.37

8 MISO Market Charges Charactized as Transmission Charges (Sum of lines 2,3,5, and 6) ($4,839,217.36)9 Accrual, Adjustments, and Other $297,993

10 Adjusted Total Settlement of MISO Market and Tariff Administation Charges/(Credits) $122,111,511

2017 - Summary of MISO Market and Tariff Administration Charges/(Credits) Settlement

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MICHIGAN PUBLIC SERVICE COMMISSION Case No.: U-20068Consumers Energy Company Exhibit No.: A-16 (MBS-1)

Page: 1 of 12017 Expense and Revenue resulting from Congestion, FTR, and ARR Transactions Witness: MBShi

Date: March 2018

(a) (b) (c) (d) (e) (f) (g) (h) (i) (j) (k) (l) (m)Line No. January February March April May June July August September October November December Total

TOTAL FTR COST1 Congestion (revenue)/expense (187,330) (46,375) (130,370) 23,014 59,629 759,509 3,381,258 651,419 (327,534) 404,123 734,451 1,738,152 7,059,9462 FTR (revenue)/expense 74,853 46,399 135,157 (23,084) (11,151) (711,156) (3,106,073) (312,508) 274,937 (259,008) (830,971) (1,649,095) (6,371,699)3 Auction (revenue)/expense 66,285 60,704 2,673 57,133 41,241 143,560 133,901 134,417 49,573 86,061 42,340 (39,432) 778,4554 Stage 2 (revenue)/expense (674,289) (674,289) (505,169) (505,272) (505,744) (520,609) (520,609) (520,609) (53,154) (53,154) (53,154) (567,950) (5,154,003)5 ARR Infeasibility Uplift expense 24,913 24,913 15,647 15,647 15,647 38,798 38,798 38,798 8,172 8,172 8,172 6,497 244,1726 Schedule 16 expense 10,788 12,786 10,994 8,487 6,360 11,359 11,261 9,338 8,535 10,591 7,178 7,170 114,848

7 Total (684,781) (575,862) (471,068) (636,316) (423,319) (419,426) (192,693) (130,889) (86,371) 113,397 (131,650) (504,659) (3,328,281)

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MICHIGAN PUBLIC SERVICE COMMISSION Case No.: U-20068Exhibit No.: A-17 (KGT-1)

Consumers Energy Company Page: 1 of 1Witness: KGTroyerDate: March 2018

(a) (b) (c) (d) (e) (f) (g) (h) (i) (j)Variable Net Fixed Energy Cost Total Cost

Line Description MWH Energy Admin Fees Energy $ Energy $ Capacity $ Total $ $/Mwh $/Mwh

Purchased & Interchange Power Received

1 Purchased Power 14,179,128 283,780,400 (957,991) 294,822,407 92,938,876 569,257,736 957,019,019 20.79 67.492 Purchased Power - PA 295 906,061 65,707,638 - 65,707,638 - 10,672,175 76,379,814 72.52 84.303 Interchange Received - Non-MISO - - - (65,459) - - (65,459) 0.00 0.004 Interchange Received - MISO 6,889,369 - - 186,806,574 - 21,452 186,828,026 27.12 27.125 Transmission - - - 352,817,669 - - 352,817,669 0.00 0.006 Short-Term Capacity Purchases - - - - - 10,464,679 10,464,679 0.00 0.007 Total P & I Received 21,974,558 349,488,038 (957,991) 900,088,830 92,938,876 590,416,042 1,583,443,748 40.96 72.06

Purchased & Interchange Power Delivered

8 Interchange Delivered - Non-MISO - - - 1,660 - - 1,660 0.00 0.009 Interchange Delivered - MISO 1,677,543 - - 63,194,871 - 1,521,643 64,716,515 37.67 38.58

10 Interchange Delivered by Counterparties - MISO 827,651 - - 23,593,944 - - 23,593,944 28.51 28.5111 Schedule 2 Reactive - - - 7,375,211 - - 7,375,211 0.00 0.0012 Total P & I Delivered 2,505,194 - - 94,165,687 - 1,521,643 95,687,330 37.59 38.20

Non PPA PA 295 PSCR Cost

13 PA 295 New Build Renewables 593,671 31,263,354 - 31,263,354 - 11,123,082 42,386,436 52.66 71.4014 Total PA 295 New Build Renewables 593,671 31,263,354 - 31,263,354 - 11,123,082 42,386,436 52.66 71.40

15 Total Net Purchased & Interchanged Power 20,063,035 380,751,392 (957,991) 837,186,497 92,938,876 600,017,481 1,530,142,853 41.73 76.27 (line 7 - line 12 + line 14)

16 Net MISO Interchange (line 4 - line 9) 5,211,826 - - 123,611,703 - (1,500,191) 122,111,511 23.72 23.43

Purchased, Interchanged, and Renewable Power TransactionsTotal Year 2017

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(a) (b) (c) (d) (e) (f) (g) (h) (i) (j) (k) (l) (m) (n)

line January February March April May June July August September October November December Total By Counterparty1 Beebe Renewable Energy (561,702)$ (680,827)$ (545,997)$ (688,737)$ (706,881)$ (563,111)$ (288,810)$ (260,443)$ (329,090)$ (636,184)$ (52,721)$ -$ (5,314,506)$ 2 Harvest II (529,357)$ (586,878)$ (516,032)$ (645,576)$ (547,300)$ (447,090)$ (310,424)$ (232,727)$ (269,131)$ (598,838)$ (188,145)$ -$ (4,871,495)$ 3 Heritage Garden (155,508)$ (143,773)$ (188,185)$ (174,165)$ (129,324)$ (104,608)$ (72,610)$ (108,480)$ (100,646)$ (221,203)$ (226,872)$ (159,052)$ (1,784,426)$ 4 Heritage Stoney Corners I Phase 2 (73,276)$ (77,968)$ (95,309)$ (95,311)$ (85,549)$ (74,900)$ (48,304)$ (53,168)$ (55,559)$ (99,225)$ (94,689)$ (31,720)$ (884,977)$ 5 Heritage Stoney Corners I Phase 3 (47,749)$ (56,457)$ (64,859)$ (62,357)$ (57,583)$ (50,670)$ (32,535)$ (37,338)$ (38,482)$ (63,991)$ (64,203)$ (28,550)$ (604,774)$ 6 Michigan Wind 2 (856,664)$ (927,301)$ (890,795)$ (1,036,695)$ (892,830)$ (698,002)$ (433,305)$ (445,024)$ (502,079)$ (578,559)$ -$ -$ (7,261,253)$ 7 WM Renewable Pine Tree Acres (276,434)$ (182,803)$ (254,579)$ (240,245)$ (263,131)$ (237,530)$ (235,570)$ (234,860)$ (281,123)$ (272,324)$ (248,605)$ (145,307)$ (2,872,512)$

8 Total (2,500,690)$ (2,656,007)$ (2,555,756)$ (2,943,086)$ (2,682,598)$ (2,175,911)$ (1,421,557)$ (1,372,040)$ (1,576,110)$ (2,470,325)$ (875,235)$ (364,629)$ (23,593,944)$

January February March April May June July August September October November December Total By Counterparty9 Beebe Renewable Energy (18,546) (26,686) (19,288) (24,260) (23,631) (19,631) (9,904) (9,550) (10,898) (22,467) (1,843) - (186,705)

10 Harvest II (17,907) (23,361) (18,907) (23,324) (18,724) (15,644) (10,404) (8,466) (9,573) (21,444) (6,290) - (174,043) 11 Heritage Garden (4,708) (5,322) (6,286) (5,594) (4,486) (3,270) (2,248) (3,375) (3,404) (6,632) (6,313) (5,567) (57,205) 12 Heritage Stoney Corners I Phase 2 (2,414) (3,064) (3,337) (3,343) (2,870) (2,688) (1,537) (1,851) (1,757) (3,467) (3,288) (1,135) (30,750) 13 Heritage Stoney Corners I Phase 3 (1,581) (2,206) (2,275) (2,187) (1,929) (1,804) (1,035) (1,295) (1,221) (2,241) (2,227) (1,009) (21,010) 14 Michigan Wind 2 (28,742) (36,556) (32,177) (37,301) (30,563) (25,236) (15,105) (16,815) (17,483) (20,243) - - (260,221) 15 WM Renewable Pine Tree Acres (8,200) (8,323) (8,845) (8,508) (9,003) (7,919) (7,785) (8,338) (8,660) (9,207) (8,660) (4,270) (97,718)

16 Total (82,098) (105,518) (91,115) (104,516) (91,205) (76,193) (48,018) (49,690) (52,995) (85,700) (28,621) (11,981) (827,651)

2017 Interchange Delivered by Counterparties to MISO

Revenue Received ($)

Energy Delivered (MWh)

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TOTAL 2017(a) (b) (c) (d) (e) (f) (g) (h) (i) (j)

VariableVariable Net Fixed Energy Cost Total Cost

Line Company Name MWH Energy $ Admin Fees $ Energy $ Energy $ Capacity $ Total $ $/Mwh $/Mwh1 Bay Windpower 2,530 132,434 (4,287) 128,147 0 0 128,147 50.64 50.642 Black River 3,878 144,889 (4,848) 140,041 0 77,126 217,167 36.11 56.003 City of Beaverton 440 13,639 (440) 13,198 0 13,551 26,750 29.96 60.734 City of Midland 1 30 (4,246) (4,216) 0 0 (4,216) (3,319.61) (3,319.61)5 Commonwealth Irving 2,536 89,332 (1,775) 87,557 0 69,621 157,178 34.53 61.996 Commonwealth Labarge 4,248 157,552 (4,248) 153,304 0 178,838 332,143 36.09 78.197 Commonwealth Middleville 1,044 39,130 (1,014) 38,116 0 350 38,466 36.50 36.848 C & C Energy LLC (C&C Electric 2) 17,343 888,240 (17,343) 870,897 0 0 870,897 50.22 50.229 Elk Rapids 2 (Energy Only) 503 14,006 0 14,006 0 0 14,006 27.83 27.83

10 Fremont Community Digester 0 19 0 19 0 0 19 45.53 45.5311 Granger - Seymour 6,289 189,505 (6,289) 183,215 46,536 267,387 497,139 29.13 79.0512 Great Lake Tissue 250 7,494 (250) 7,244 0 0 7,244 28.95 28.9513 Green Meadow Farms 35 772 0 772 0 0 772 22.38 22.3814 Grenfell Hydro 1,882 70,133 (1,882) 68,251 0 69,375 137,625 36.26 73.1215 MAHLE Engine Components 99 2,504 (4,244) (1,739) 0 0 (1,739) (17.51) (17.51)16 Michiana Hydro 242 8,940 (242) 8,698 0 12,146 20,844 36.00 86.2817 Michigan State University 2,126 65,504 (1,463) 64,041 0 0 64,041 30.13 30.1318 NANR - Rathbun 6,975 368,538 (7,000) 361,538 0 0 361,538 51.83 51.8319 STS Cascade 8,048 247,967 (8,048) 239,919 0 313,274 553,192 29.81 68.7320 STS Fallasburg 4,742 146,137 (4,742) 141,396 0 134,355 275,750 29.82 58.1521 STS Morrow 3,608 111,585 (3,608) 107,978 0 131,157 239,135 29.93 66.2822 STS Ada 6,543 201,928 (6,543) 195,385 0 201,202 396,587 29.86 60.6123 Venice Park 7,909 427,863 (8,979) 418,884 0 0 418,884 52.96 52.9624 White's Bridge 3,515 130,642 (3,515) 127,127 0 121,117 248,244 36.17 70.6325 Ada Cogeneration 165,667 4,999,639 (24,000) 4,975,639 1,869,428 9,342,870 16,187,937 30.03 97.7126 Adrian Energy 15,738 596,770 (15,902) 580,868 0 681,956 1,262,824 36.91 80.2427 Apple Blossom Wind Farm 13,228 348,671 0 348,671 0 0 348,671 26.36 26.3628 Boyce Hydro 44,319 1,793,281 0 1,793,281 0 1,066,726 2,860,007 40.46 64.5329 Cadillac Renewable 137,864 3,992,913 (24,000) 3,968,913 2,183,944 11,276,523 17,429,379 28.79 126.4230 Entergy Palisades 6,780,140 45,483,100 0 45,483,100 0 320,470,942 365,954,042 6.71 53.9731 Filer City 488,490 18,315,552 (24,000) 18,291,552 0 24,491,178 42,782,730 37.45 87.5832 C & C Energy LLC (C&C Electric 1) 14,441 437,488 (14,384) 423,104 110,274 614,569 1,147,946 29.30 79.4933 Genesse Power Station 98,073 2,565,240 (24,000) 2,541,240 2,214,612 13,389,286 18,145,138 25.91 185.0234 Granger - Byron Center 29,474 889,825 (29,351) 860,474 222,331 1,195,252 2,278,057 29.19 77.2935 Granger - Grand Blanc 22,702 687,365 (22,841) 664,525 172,639 971,305 1,808,468 29.27 79.6636 Granger - Ottawa 28,956 874,405 (29,340) 845,065 217,516 1,231,379 2,293,959 29.18 79.2237 Granger - Pinconning 18,204 550,753 (18,116) 532,638 137,935 769,123 1,439,696 29.26 79.0938 Grayling 159,446 4,600,582 (42,543) 4,558,039 2,179,611 11,699,452 18,437,102 28.59 115.6339 Hillman Limited 133,240 5,041,234 (130,868) 4,910,366 0 4,709,484 9,619,850 36.85 72.2040 Kent County 99,572 3,740,497 (24,000) 3,716,497 0 4,865,672 8,582,170 37.32 86.1941 Michigan Power Limited 999,906 37,650,197 (24,000) 37,626,197 0 37,434,161 75,060,358 37.63 75.0742 Michigan Wind 1, LLC 170,902 9,016,738 (72,237) 8,944,500 0 0 8,944,500 52.34 52.3443 North American Resources (Peoples) 18,321 555,260 (17,790) 537,470 140,014 779,300 1,456,784 29.34 79.5244 Viking - Lincoln 144,389 5,461,160 (144,579) 5,316,582 0 5,683,597 11,000,178 36.82 76.1845 Viking - McBain 143,232 5,415,379 (144,265) 5,271,114 0 5,639,057 10,910,171 36.80 76.1746 WM Renewable Energy 12,754 386,399 (12,769) 373,629 96,915 518,571 989,115 29.29 77.5547 MCV 4,355,283 126,919,168 (24,000) 126,895,168 83,347,122 110,837,835 321,080,126 29.14 73.7248 SUBTOTAL 14,179,128 283,780,400 (957,991) 282,822,410 92,938,877 569,257,736 945,019,022 19.95 66.6549 Biomass Merchant Plant 0 0 0 11,999,997 0 0 11,999,997 0.00 0.0050 TOTAL 14,179,128 283,780,400 (957,991) 294,822,407 92,938,877 569,257,736 957,019,019 20.79 67.49

PURCHASED POWER AND COGENERATION - ENERGY AND EXPENSE

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PURCHASED POWER CONTRACT RATES AND MPSC APPROVAL ORDERSENERGY AND CAPACITY CONTRACTS

(a) (b) (c) (d) (e) (f) (g) (h) (i)

On-Peak Off-Peak On-Peak Off-Peak RateMW ¢/kWh ¢/kWh ¢/kWh ¢/kWh ¢/kWh

1 Ada Cogeneration Ltd Partnership 29.400 4.024 3.822 0.100 Not to exceed $2,000/month June 22, 1989 – U-8871/U-8833

2 Adrian Energy Associates 2.500 4.476 4.253 0.100 Not to exceed $2,000/month March 31, 1993 – U-10127

3 Black River Power Limited Partnership 0.840 2.200 1.870 0.125 December 12, 1988 - U-8866

4 Beaverton, City of 0.500 3.510 2.750 0.100 December 12, 1988 - U-8866

5 Boyce Hydro Power, LLC (f/k/a Wolverine Power Corporation) 11.000 4.670 3.660 2.330 1.970 None December 13, 1988 - U-8866

6 C&C Energy, LLC - C&C 1 (f/k/a Gas Recovery Systems) 2.750 4.374 4.155 0.100 Min of $348/Mo, but not to exceed $3,480/Mo July 21, 1993 – U-10270

7 Cadillac Renewable Energy 34.000 4.320 4.110 0.100 Not to exceed $2,000/month June 22, 1989 – U-8871

8 Commonwealth Power Company – Irving 0.240 4.034 3.832 0.100 Not to exceed $2,000/month March 31, 1993 – U-10127

9 Commonwealth Power Company – LaBarge 0.700 4.520 3.970 0.100 December 13, 1988 - U-8866

10 Commonwealth Power Company – Middleville 0.200 4.034 3.832 0.100 Not to exceed $2,000/month March 31, 1993 – U-10127

11 Entergy Nuclear Power Marketing (Palisades) 813.000 None March 27, 2007 - U-14992

12 Genesee Power Station Limited Partnership 35.000 4.650 4.420 0.100 Min of $200/mo, but not to exceed $2,000/mo June 22, 1989 - U-8871

13 Energy Developments Grand Blanc, LLC (f/k/aGranger Electric Company – Grand Blanc) 3.812 4.402 4.182 0.100 Min of $348/Mo, but not to exceed $3,480/Mo Jule 21, 1993 - U-10276

14 Energy Developments Pinconning, LLC (f/k/aGranger Electric of Pinconning) 3.042 4.348 4.136 0.100 Min of $236/mo, but not to exceed $2,361/mo June 22, 1989 - U-8871/U-10267

15 Energy Developments Byron Center, LLC (f/k/aGranger Electric of Byron Center) 3.792 4.184 3.970 0.100 Min of $258/mo, but not to exceed $2,582/mo June 22, 1989 - U-8871/U-10273

16 Energy Developments Coopersville, LLC (f/k/a Granger Electric of Coopersville, LLC - Ottawa) 4.565 4.374 4.155 0.100 Min of $348/Mo, but not to exceed $3,480/Mo MPSC Order Approving

Capacity Rate

17 Energy Developments Coopersville, LLC (f/k/a Granger Electric Company of Coopersville – Seymour) 0.752 4.374 4.155 0.100 Min of $348/Mo, but not to exceed $3,480/Mo Jule 21, 1993 - U-10275

18 Grayling Generating Station Limited Partnership 36.170 4.180 3.970 0.100 Min of $348/Mo, but not to exceed $3,480/Mo June 22, 1989 - U-8871/U-10274

19 Grenfell Hydro, Inc 0.300 4.020 3.420 0.100 December 13, 1988 - U-8866

20 Hillman Power Company LLC 18.000 3.850 3.270 0.100 August 18, 1984 - U-7990

21 Kent County 15.680 5.340 4.540 0.100 Not to exceed $2,000/month February 19, 1987 - U-8639

22 Michiana Hydroelectric Co (Bellevue) 0.075 5.360 4.760 0.100 December 13, 1988 - U-8866

23 Michigan Power Limited Partnership 123.000 3.880 3.686 0.100 Not to exceed $2,000/month March 31, 1993 – U-10127

24 Midland Cogeneration Venture Limited Partnership 1240.000 1.014 1.014 0.100 Not to exceed $2,000/month June 10, 2008 - U-15320

Line Energy & Capacity Company Capability Variable Energy Rate MPSC Order Approving Capacity RateSpecial Notes

Twelve-month rolling average cost of CE


Capacity Rate Admistrative Charge








4.736

MCV Cost of Production













0.664

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PURCHASED POWER CONTRACT RATES AND MPSC APPROVAL ORDERSENERGY AND CAPACITY CONTRACTS - CONTINUED

(a) (b) (c) (d) (e) (f) (g) (h) (i)


25 North American Natural Resources -Peoples 3.061 4.374 4.155 0.100 Min of $348/Mo, but not to exceed $3,480/Mo July 21, 1993 – U-10266

26 STS Hydropower Ltd - Ada Hydro Plant 1.400 3.670 2.870 3.350 2.850 0.100 June 23, 2107 -U-18425

27 STS Hydropower Ltd – Cascade Hydro Plant 1.400 3.670 2.870 4.250 3.610 0.100 December 13, 1988 - U-8866

28 STS Hydropower Ltd – Fallasburg Hydro Plant 0.850 3.670 2.870 3.090 2.630 0.100 December 13, 1988 - U-8866

29 STS Hydropower Ltd – Morrow Hydro Plant 1.000 3.670 2.870 3.970 3.370 0.100 December 13, 1988 - U-8868

30 T.E.S. Filer City Station Limited Partnership 50.000 6.550 5.550 0.100 Not to exceed $2,000/month February 19, 1987 - U-8562

31 Thornapple Association, Inc (terminated June 1, 2017) 1.400 3.670 2.870 4.250 3.610 0.100 December 17, 1986 - U-8286

32 Viking Energy of Lincoln, LLC 18.000 4.300 3.660 0.100 November 14, 1984 - U-8062

33 Viking Energy of McBain, LLC 18.000 4.300 3.660 0.100 November 14, 1984 - U-8062

34 White's Bridge Hydro Company 0.817 3.760 3.200 0.100 December 17, 1985 - U-8042

35 WM Renewable Energy - Venice Park (f/k/a Bio Energy Partners) 1.500 4.190 3.980 0.100 Min of $200/mo, but not to exceed $2,000/mo June 22, 1989 – U-8871/U-10272

PURCHASED POWER CONTRACT RATES AND MPSC APPROVAL ORDERS

ENERGY-ONLY CONTRACTS


36 Great Lakes Tissue Company N/A - - 0.100 Not to exceed $2,000/month

37 Michigan State University N/A - - 0.100 Not to exceed $200/month

38 City of Midland N/A - - 0.100 Min of $348/Mo, but not to exceed $3,480/Mo

39 Western Michigan University N/A - - 0.100 Min of $348/Mo, but not to exceed $3,480/Mo

40 Grand Valley State University N/A - - None

41 Mahle Engine Components USA, Inc. N/A - - 0.100 Min of $348/Mo, but not to exceed $3,480/Mo


Line Energy & Capacity Company Capability Variable Energy Rate MPSC Order Approving Capacity RateSpecial Notes



Capacity Rate Admistrative Charge




Line Energy-Only Company Capability Variable Energy RateSpecial Notes

Three-month rolling average top

Three-month rolling average top

Admistrative ChargeCapacity Rate

90% of (Load Locational Marginal

90% of (Load Locational Marginal

Hourly top incremental cost

90% of the hourly top incremental cost

MPSC Order Approving Capacity Rate



PURCHASED POWER CONTRACT RATES AND MPSC APPROVAL ORDERSRENEWABLE RESOURCE PROGRAM CONTRACTS

(a) (b) (c) (d) (e) (f) (g) (h) (i)


42 Bay Windpower I 1.800 Redacted Redacted 0.100 Min of $348/Mo, but not to exceed $3,480/Mo October 18, 2005 - U-14626

43 C&C Energy, LLC (C&C Electric 2 Plant) 2.500 4.392 4.392 0.100 Min of $348/Mo, but not to exceed $3,480/Mo October 18, 2005 - U-14626

44 North American Natural Resources (Venice Park), combination of White Lake, Venice Park second unit, Peoples fourth unit 3.200 3.723 3.523 0.100 Min of $348/Mo, but not to exceed $3,480/Mo October 18, 2005 - U-14626

45 Michigan Wind I, LLC (f/k/a Noble Thumb Windpark, LLC.) 57.000 3.290 3.290 0.100 Min of $348/Mo, but not to exceed $3,480/Mo October 18, 2005 - U-14626

46 Michigan Wind I, LLC (f/k/a Noble Thumb Windpark, LLC.) 12.000 Redacted Redacted 0.100 Min of $348/Mo, but not to exceed $3,480/Mo October 18, 2005 - U-14626

47 North American Natural Resources (Rathbun) 1.600 3.723 3.523 0.100 Min of $348/Mo, but not to exceed $3,480/Mo January 25, 2010 - U-15675

Special Notes

Average PSCR cost

Average PSCR cost

Line Renewable Resource Company Capability Variable Energy Rate Renewable Rate Admistrative Charge

Average PSCR cost

Average PSCR cost

Average PSCR cost

Average PSCR cost




PURCHASED POWER CONTRACT RATES AND MPSC APPROVAL ORDERSPUBLIC ACT 295 CONTRACTS

(a) (b) (c) (d) (e) (e) (f)Capacity RECPrice(1) On-Peak Off-Peak Price

MW $/MW - Month $/MWh $/MWh $/REC

48 Apple Blossom Wind, LLC (f/k/a Geronimo Huron Wind, LLC) 100.000 Redacted Redacted November 19, 2015 - U15805

49 Beebe Renewable Energy FKA Blissfield 81.600 Redacted Redacted July 27, 2010 - U-15805

50 Elk Rapids 0.700 0.00 53.00 October 13, 2009 - U-15805

51 Fremont Community Digester 2.850 29,963.06 45.56 October 13, 2009 - U-15805

52 Harvest II Windfarm 59.400 Redacted Redacted July 27, 2010 - U-15805

53 Heritage Garden Wind Farm I 20.000 Redacted Redacted November 19, 2010 - U-15805

54 Heritage Stoney Corners Wind Farm I (Phase 2) 12.250 Redacted Redacted November 19, 2010 - U-15805

55 Heritage Stoney Corners Wind Farm I (Phase 3) 8.350 Redacted Redacted January 26, 2012 - U-15805

56 Michigan Wind 2 90.000 Redacted Redacted July 27, 2010 - U-15805

57 North American Natural Resources (Lennon) 1.600 0.00 48.52 October 13, 2009 - U-15805

57 WM Renewable Energy (Northern Oaks) 1.600 3,000.00 12.00 October 13, 2009 - U-15805

58 WM Renewable Energy (Pine Tree Acres) 12.800 Redacted Redacted July 27, 2010 - U-15805

Capacity RECPrice(1) On-Peak Off-Peak Price


59 Brook View Dairy 0.600 0.00 0.00 April 23, 2015 - U-15805

60 Green Meadow Farms, Inc. 0.800 0.00 0.00 April 23, 2015 - U-15805

61 Scenic View Dairy 0.400 0.00 0.00 April 23, 2015 - U-15805

(1) Capacity price is paid on Resource Adequacy Capacity.(2) Weighted average of $27.23/MWh on-peak and $25.23/MWh off-peak. There is no compensation for incentive RECs.

Day-Ahead LMP

Day-Ahead LMP


2009 Renewable Energy Plan forecasted






Day-Ahead LMP

Line Public Act 295 Company Nameplate Capacity Variable Energy Rate

Day-Ahead LMP


86

Scheduled Rate 76.39 - 106.39

86

PURCHASED POWER CONTRACT RATES AND MPSC APPROVAL ORDERSPUBLIC ACT 295 CONTRACTS - EXPERIMENTAL ADVANCED RENEWABLE PROGRAM - ANAEROBIC DIGESTION

Line Public Act 295 Company Nameplate Capacity Variable Energy Rate MPSC Order Approving Capacity Rate



PURCHASED POWER CONTRACT RATES AND MPSC APPROVAL ORDERSPUBLIC ACT 295 CONTRACTS - EXPERIMENTAL ADVANCED RENEWABLE PROGRAM - SOLAR

(a) (b) (c) (d) (e) (e) (f)Capacity RECPrice(1) On-Peak Off-Peak Price


62 Experimental Advanced Renewable Program ("EARP") residential Phase 1 0.180 - - December 21, 2010 - U-15805

63 Experimental Advanced Renewable Program ("EARP") non- residential Phase 1 1.002 - - December 21, 2010 - U-15805

64 Experimental Advanced Renewable Program ("EARP") residential Phase 2 0.291 - - May 10, 2011 - U-15805

65 Experimental Advanced Renewable Program ("EARP") non-residential Phase 2 0.548 - - May 10, 2011 - U-15805

66 Experimental Advanced Renewable Program ("EARP") non-residential Phase 3 0.024 - - February 28, 2013 - U-15805

67 Experimental Advanced Renewable Program ("EARP") residential Phase 4 0.108 - - February 28, 2013 - U-15805












79 Experimental Advanced Renewable Program ("EARP") residential Phase 16 0.104 - - April 23, 2015 - U-15805

80 Experimental Advanced Renewable Program ("EARP") non-residential Phase 17 0.171 - - April 23, 2015 - U-15805



83 Experimental Advanced Renewable Program ("EARP") non-residential Phase 20 0.580 - - April 23, 2015 - U-15805












(1) Constracts awarded as part of EARP since Phase 3 inlcude a provision to pay an additional $1/MWh if certain conditions are satisfied. Most participants failed to satisfy the incentive provision.

199 (1)

199 (1)

240 (1)

240 (1)

199 (1)

240 (1)

240 (1)

240 (1)

199 (1)

240 (1)

240 (1)

243 (1)

199 (1)

243 (1)

243 (1)

199 (1)

Line Public Act 295 Company Nameplate Capacity Variable Energy MPSC Order Approving Capacity Rate

249 (1)

650

450

525

375

229 (1)

259 (1)

229 (1)

259 (1)

249 (1)

219 (1)

249 (1)

209 (1)

249 (1)

243 (1)

199 (1)

243 (1)

MICHIGAN PUBLIC SERVICE COMMISSIONConsumers Energy Company2016 Karn Unit 1 Outage Event No. 76

Case No.: U-20068 Exhibit No.: A-21 (DBK-8) Page: 1 of 1Witness: DBKehoeDate: January 2019

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michigan public service commission case no.: u-20068

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