COMMONWEALTH OF KENTUCKY
BEFORE THE PUBLIC SERVICE COMMISSION

In the Matter of:
APPLICATION OF KENTUCKY UTILITIES
COMPANY FOR AN ADJUSTMENT OF ITS
ELECTRIC RATES AND FOR CERTIFICATES
OF PUBLIC CONVENIENCE AND NECESSITY

)
)
)
)

CASE NO.
2016-00370

RESPONSE OF
KENTUCKY UTILITIES COMPANY
TO
THE ATTORNEY GENERAL’S SUPPLEMENTAL DATA REQUESTS
DATED FEBRUARY 7, 2017

FILED: FEBRUARY 20, 2017

 VERIFICATION
COMMONWEALTH OF KENTUCKY )
)
COUNTY OF JEFFERSON
)

SS:

The undersigned, Daniel K. Arbough, being duly sworn, deposes and says that
he is Treasurer for Louisville Gas and Electric Company and Kentucky Utilities
Company and an employee of LG&E and KU Services Company, and that he has
personal knowledge of the matters set forth in the responses for which he is identified as
the witness, and the answers contained therein are true and correct to the best of his
information, knowledge and belief.

Subscribed and sworn to before me, a Notary Public in and before said County
and State, this

rf.$14 day of ~

2017.

_Cl/1,,_..,../~t
~~...,.,-....h~~~~
' ~J
___(SEAL)
No~~;J
My Commission Expires:
JUDY SCHOOLER
M:>tary Public, State at Large, KY
lltl commission expires July 11. 2018
Notary ID# 512743

 VERIFICATION
COMMONWEALTH OF KENTUCKY
COUNTY OF JEFFERSON

)
)
)

SS:

The undersigned, Lonnie E. Bellar, being duly sworn, deposes and says that he is
Senior Vice President - Operations for Louisville Gas and Electric Company and
Kentucky Utilities Company and an employee of LG&E and KU Services Company, and
that he has personal knowledge of the matters set forth in the responses for which he is
identified as the witness, and the answers contained therein are true and correct to the
best of his information, knowledge and belief.

Subscribed and sworn to before me, a Notary Public in and before said County
and State, this

J.+-')</4 day of ~

My Commission Expires:

JUDY SCHOOLER
Notary Public, State at Large, KY
My eommissior:a expii:es .!11!y 11, 2018
Notary ID# 512743

2017.

 VERIFICATION
COMMONWEALTH OF KENTUCKY
COUNTY OF JEFFERSON

)
)
)

SS:

The undersigned, Kent W. Blake, being duly sworn, deposes and says that he is
Chief Financial Officer for Kentucky Utilities Company and Louisville Gas and Electric
Company and an employee of LG&E and KU Services Company, and that he has
personal knowledge of the matters set forth in the responses for which he is identified as
the witness, and the answers contained therein are true and correct to the best of his
information, knowledge and belief.

/(f tJ61Jv_
Kent W. Blake

Subscribed and sworn to before me, a Notary Public in and before said County
and State, this

G/Sit..

day of _
~
--·~~~
·~_,....___ _ _ _ _ 2017.

N--f!-tar-~---'
P-=u'blfc]
"-'-~ic--+1-~~·(L'-'-'-'-l',rt'--1-----(SEAL)
My Commission Expires:

 VERIFICATION
COMMONWEALTH OF KENTUCKY
COUNTY OF JEFFERSON

)
)
)

SS:

The undersigned, Robert M. Conroy, being duly sworn, deposes and says that he
is Vice President - State Regulation and Rates for Louisville Gas and Electric Company
and Kentucky Utilities Company, an employee of LG&E and KU Services Company, and
that he has personal knowledge of the matters set forth in the responses for which he is
identified as the witness, and the answers contained therein are true and correct to the
best of his information, knowledge and belief.

MAm

Robert M. Conroy

Subscribed and sworn to before me, a Notary Public in and before said County
and State, this ";;l..3 .,\ day of

-::::S--fLI\l llU"\ \

2017.

~~

Notary Public

My Commission Expires:

SUSAN M. MTKINS
Notary Pubfic, Si8t8 al Lll'gi, KY
My Commission EJCpir9a Mcr.19, 2017
Notary ID# 485723

(SEAL)

 VERIFICATION
COMMONWEALTH OF KENTUCKY )
)
COUNTY OF JEFFERSON
)

SS:

The undersigned, Christopher M. Garrett, being duly sworn, deposes and says
that he is Director - Rates for Kentucky Utilities Company and Louisville Gas and
Electric Company and an employee of LG&E and KU Services Company, that he has
personal knowledge of the matters set forth in the responses for which he is identified as
the witness, and the answers contained therein are true and correct to the best of his
information, knowledge and belief.

Subscribed and sworn to before me, a Notary Public in and before said County
and State, this

/t)flt

day of

<po,/~

2017.

N_0_ ,~'fy"" "''f4
" "ub''-= " " '1t~L. . . . . . .=c.=. . o~" - "-=-J- -(SEAL)
My Commission Expires:

JUDY SCHOOLER
Notary Public, State at L.srge, KY
My commission expires July 11, 2018
Notary 10 # 512743

 VERIFICATION
COMMONWEALTH OF KENTUCKY

)

)
COUNTY OF JEFFERSON

SS:

)

The undersigned, John P. Malloy, being duly sworn, deposes and says that he is
Vice President - Gas Distribution for Louisville Gas and Electric Company and
Kentucky Utilities Company, an employee of LG&E and KU Services Company, and that
he has personal knowledge of the matters set forth in the responses for which he is
identified as the witness, and the answers contained therein are true and correct to the
best of his information, knowledge and belief.

Subscribed and sworn to before me, a Notary Public in and before said County
and State,

this~ day of ~-<.A-'!/"

My Commission Expires:
JUDY SCHOOLER
~ry Public, State at Large, KY
~ commisskm &*f)iles Jllly 11, 2018
Notary ID 'If. 512743

2017.

 VERIFICATION

STATE OF TEXAS

)

COUNTY OF TRAVIS

)

)

SS:

The undersigned, Adrien M. McKenzie, being duly sworn, deposes and says he
is President of FINCAP, Inc., that he has personal knowledge of the matters set forth in
the responses for which he is identified as the witness, and the answers contained therein
are true and correct to the best of his information, knowledge and belief

Adrien M. McKenzie

Subscribed and sworn to before me, a Notary Public in and before said County
and State, this

\'1i1'

day of

~v.o.rvj

2017.

1f
-o~~
~~Pu~f-lic_f1f'g,b~----(SEAL)
My Commission Expires:

e

ROBERT LEE MARTINEZ
NOTARY PUBLIC STATE OF TEXAS
MY COMM. EXP. 4/17/2019
NOTARY ID 13019391-2

 VERIFICATION
COMMONWEALTH OF KENTUCKY

)

)
COUNTY OF JEFFERSON

SS:

)

The undersigned, Gregory J. Meiman, being duly sworn, deposes and says that
he is Vice President, Human Resources for Louisville Gas and Electric Company and
Kentucky Utilities Company, an employee of LG&E and KU Services Company, and that
he has personal knowledge of the matters set forth in the responses for which he is
identified as the witness, and the answers contained therein are true and correct to the
best of his information, knowledge and belief.

(

Subscribed and sworn to before me, a Notary Public in and before said County
and State, this

J§'/ti day of

~..t..ULV;JL

2017.

(SEAL)

My Commission Expires:
JUDY SCHOOLER
Notary Public, State at Large, KY
My commission expires July 11, 201 s
Notary ID# 512743

 VERIFICATION
COMMONWEALTH OF KENTUCKY )
)
COUNTY OF JEFFERSON
)

SS:

The undersigned, Valerie L. Scott, being duly sworn, deposes and says that she is
Controller for Kentucky Utilities Company and Louisville Gas and Electric Company and
an employee of LG&E and KU Services Company, and that she has personal knowledge
of the matters set forth in the responses for which she is identified as the witness, and the
answers contained therein are true and correct to the best of her information, knowledge
and belief.

Valerie L. Scott

Subscribed and sworn to before me, a Notary Public in and before said County
and State, this

j!J/;( day of ~

2017.

--r1~.....,._.'b=·=l-f~~~~~_..___ _

(SEAL)

NoJf;P\lb1iC?'

My Commission Expires:

JUDY SCHOOLER
Notary Public, State at Large, KY

It/ commission expires .July 11, 2018
Notary ID# 51274~

 VERIFICATION

COMMONWEALTH OF KENTUCKY
COUNTY OF JEFFERSON

)
)
)

SS:

The undersigned, William Steven Seelye, being duly sworn, deposes and states
that he is a Principal of The Prime Group, LLC, that he has personal knowledge of the
matters set forth in the responses for which he is identified as the witness, and the
answers contained therein are true and correct to the best of his information, knowledge
and belief.

William Steve

Subscribed and sworn to before me, a Notary Public in and before said County

and State, this ) (}#day of

?.zi,ULY

2017.

~~-~~

No ry Publi
My Commission Expires:

JUDY SCHOUU:R
Notary Public, State at Large, KY
My commissior:l expires .luly 11, 2018
Notary ID# 512743

(SEAL)

 VERIFICATION
COMMONWEALTH OF KENTUCKY )
)
COUNTY OF JEFFERSON
)

SS:

The undersigned, David S. Sinclair, being duly sworn, deposes and says that he
is Vice President, Energy Supply and Analysis for Kentucky Utilities Company and
Louisville Gas and Electric Company and an employee of LG&E and KU Services
Company, and that he has personal knowledge of the matters set forth in the responses for
which he is identified as the witness, and the answers contained therein are true and
correct to the best of his information, knowledge and belief.

David S. Sinriai;

'

Subscribed and sworn to before me, a Notary Public in and before said County
and State, this

Js:cf4 day of~~µ..=.L.Af
~l<L....~=-=--1,L/_ _ _ _ _ _ _ 2017.

My Commission Expires:
JUDY SCHOOLER
Notary Public, State at Large, KY
My rommission expires .July 11, 2018
Notary ID # 512743

 VERIFICATION

COMMONWEAL TH OF PENNSYLVANIA

)

COUNTY OF CUMBERLAND

)
)

SS:

The undersigned, John J. Spanos, being duly sworn, deposes and says he is Senior
Vice President, for Gannett Fleming Valuation and Rate Consultants, LLC, that he has
personal knowledge of the matters set forth in the responses for which he is identified as
the witness, and the answers contained therein are true and correct to the best of his
information, knowledge and belief.

Subscribed and sworn to before me, a Notary Public in and before said County and
Commonwealth, this

/~ay of _..),,£,~od!lt.,,c.....o~-2017.

~~;:J

i<Jotar

c

My Commission Expires:
COMMONWEALTH OF PENNSYLVANIA
NOTARIAL SEAL
Cheryl Ann Rutter, Notary Public
East Pennsboro Twp., Cumberland County
My Commission Expires Feb. 20, 2019
MEM

ER,

PENNSYLVANIA ASSOCIATION OF NOT.C.RIES

(SEAL)

 VERIFICATION
COMMONWEALTH OF KENTUCKY )

)
COUNTY OF JEFFERSON

SS:

)

The undersigned, John K. Wolfe, being duly sworn, deposes and says that he is
Vice President - Electric Distribution for Kentucky Utilities Company and Louisville Gas
and Electric Company and an employee of LG&E and KU Services Company, and that
he has personal knowledge of the matters set forth in the responses for which he is
identified as the witness, and the answers contained therein are true and correct to the
best of his information, knowledge and belief.

Subscribed and sworn to before me, a Notary Public in and before said County

andState,this

.2'~ dayof ~~

My Commission Expires:

JUDY SCHOOLER
Notary Public, State at Large, KY
My eemmission expires July 11, 201 B
Notary ID# 512743

2011.

 Response to AG-2 Question No. 1
Page 1 of 2
Garrett
KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 1
Responding Witness: Christopher M. Garrett
Q-1.

Refer to the Company’s response to AG-1-36.
a. Has the Company included any asset in rate base relating to the Accumulated
Deferred Income Tax balance for CCR Pond Closures? If so, identify,
quantify and explain the related asset.
b. Referring to the amount of ADIT for "FAC Under Recovery KY-Current"
identify the amount of FAC under (or over) recovery (1) for the 13 month
average ending February 28, 2017 ("base period") and (2) as projected for the
twelve-month forecasted test period beginning July 1, 2017, and ending June
30, 2018 ("forecasted Test Year").
c. Show in detail how the Federal NOL amount was derived.
d. Identify, quantify and provide all projections as to when the Company expects
to utilize the Federal NOL to reduce income taxes.
e. How much of the Federal NOL relates to accelerated tax depreciation
including bonus tax depreciation? Identify, quantify and explain the amounts.
f. How much of the Federal NOL relates to tax deductions other than accelerated
tax depreciation including bonus tax depreciation? Identify, quantify and
explain the amounts.
g. Referring to the ADIT balance for Pensions - Regulatory Asset, has the
Company included any asset in rate base relating to that ADIT component? If
not, explain fully why not. If so, identify, quantify and explain the related
asset.

A-1.
a. No, accumulated deferred income taxes associated with CCR Pond Closures
are eliminated through the ECR rate base adjustment.
b. See attached.

 Response to AG-2 Question No. 1
Page 2 of 2
Garrett

c. See attached.
d. See attached.
e. The Federal NOL is based on the level of pre-tax income and various tax
deductions. Accelerated tax depreciation, including bonus depreciation is the
company’s largest tax deduction that contributes to the Federal NOL, but the
Federal NOL is not tracked or measured by individual tax deductions.
f. See the response to part e.
g. The Company has not included in rate base the Pension – Regulatory Asset.
The Company has included an ADIT liability in rate base that relates to the
Pension Regulatory Asset. The 13 month average liability is $38,923,525.
An offsetting ADIT asset is also included in rate base associated with the
corresponding increase in the pension liability recognized as part of the
Pension - Regulatory Asset journal entry.

 Attachment 1 to Response to KU AG-2 Question No. 1(b)
Page 1 of 1
Garrett
KENTUCKY UTILITIES COMPANY
Accumulated Deferred Taxes on Income
FAC Under Recovery KY-Current
As of February 28, 2017
Reg 1.167(l)-(h)(6)ii
(Dollars)
Line
No.

Amount

1

Accumulated Deferred Taxes at February 29, 2016

2

Projected Accumulated Deferred Taxes at February 28, 2017

3

Change in Accumulated Deferred Taxes for the base year

4

Balance February 29, 2016

5

March 1-31, 2016

6

Monthly Increase/Decrease

$

$

3,512,055
1,865,192

Proration

(137,239)

335/365

April 1-30, 2016

(137,239)

7

May 1-31, 2016

8

$

(1,646,863)

$

3,512,055

Activity

$

(125,959)

3,386,096

305/365

(114,679)

3,271,417

(137,239)

274/365

(103,023)

3,168,394

June 1-30, 2016

(137,239)

244/365

(91,743)

3,076,651

9

July 1-31, 2016

(137,239)

213/365

(80,087)

2,996,564

10

August 1-31, 2016

(137,239)

182/365

(68,431)

2,928,133

11

September 1-30, 2016

(137,239)

152/365

(57,151)

2,870,982

12

October 1-31, 2016

(137,239)

121/365

(45,496)

2,825,486

13

November 1-30, 2016

(137,239)

91/365

(34,216)

2,791,270

14

December 1-31, 2016

(137,239)

60/365

(22,560)

2,768,710

15

January 1-31, 2017

(137,239)

29/365

(10,904)

2,757,806

16

February 1-28, 2017

(137,239)

1/365

(376)

2,757,430

17

13 Month Average with pro rata ending Deferred Taxes at February 28, 2017

$

3,008,538

 Attachment 2 to Response to KU AG-2 Question No. 1(b)
Page 1 of 1
Garrett
KENTUCKY UTILITIES COMPANY
Accumulated Deferred Taxes on Income
FAC Under Recovery KY-Current
As of June 30, 2018
Reg 1.167(l)-(h)(6)ii
(Dollars)
Line
No.

Amount

1

Projected Accumulated Deferred Taxes at June 30, 2017

2

Projected Accumulated Deferred Taxes at June 30, 2018

3

Change in Accumulated Deferred Taxes for the forward year

4

Balance June 30, 2017

5

July 1-31, 2017

6

Monthly Increase/Decrease

$

$

1,933,286
2,148,428

Proration

11,349

335/365

August 1-31, 2017

11,349

7

September 1-30, 2017

8

$

215,142

$

1,933,286

Activity

$

10,416

1,943,702

304/365

9,452

1,953,154

11,349

274/365

8,520

1,961,674

October 1-31, 2017

11,349

243/365

7,556

1,969,230

9

November 1-30, 2017

11,349

213/365

6,623

1,975,853

10

December 1-31, 2017

11,349

182/365

5,659

1,981,512

11

January 1-31, 2018

24,508

151/365

10,139

1,991,651

12

February 1-28, 2018

24,508

123/365

8,259

1,999,910

13

March 1-31, 2018

24,508

92/365

6,177

2,006,087

14

April 1-30, 2018

24,508

62/365

4,163

2,010,250

15

May 1-31, 2018

24,508

31/365

2,082

2,012,332

16

June 1-30, 2018

24,508

1/365

67

2,012,399

17

13 Month Average with pro rata ending Deferred Taxes at June 30, 2018

$

1,980,849

 Attachment to Response to KU AG-2 Question No. 1(c)
Page 1 of 1
Garrett
KENTUCKY UTILITIES COMPANY
Accumulated Deferred Taxes on Income
Federal Net Operating Losses
As of June 30, 2018
Reg 1.167(l)-(h)(6)ii
(Dollars)
Line
No.

Amount

1

Projected Accumulated Deferred Taxes at June 30, 2017

2

Projected Accumulated Deferred Taxes at June 30, 2018

3

Change in Accumulated Deferred Taxes for the forward year

4

Balance June 30, 2017

5

July 1-31, 2017

6

Monthly Increase/Decrease

$

$

47,115,205
30,251,121

Proration

(4,395,220)

335/365

August 1-31, 2017

(4,395,220)

7

September 1-30, 2017

8

$

(16,864,084)

$

47,115,205

Activity

$

(4,033,969)

43,081,236

304/365

(3,660,677)

39,420,559

(4,395,220)

274/365

(3,299,426)

36,121,133

October 1-31, 2017

(4,395,220)

243/365

(2,926,133)

33,195,000

9

November 1-30, 2017

(4,395,220)

213/365

(2,564,882)

30,630,118

10

December 1-31, 2017

(4,395,220)

182/365

(2,191,589)

28,438,529

11

January 1-31, 2018

1,584,540

151/365

655,522

29,094,051

12

February 1-28, 2018

1,584,540

123/365

533,968

29,628,019

13

March 1-31, 2018

1,584,540

92/365

399,391

30,027,410

14

April 1-30, 2018

1,584,540

62/365

269,155

30,296,565

15

May 1-31, 2018

1,584,540

31/365

134,577

30,431,142

16

June 1-30, 2018

1,584,540

1/365

4,341

30,435,483

17

13 Month Average with pro rata ending Deferred Taxes at June 30, 2018

$

33,685,727

 Kentucky Utilities Company
Net Operating Losses
$ thousands

Actual
Line No.

Aug 2016

1
2
3
4
5
6
7

KU Taxable Income/(Loss)
NOL Added/(Utilization)
Taxable Income After NOL
Sec 199 Deduction
Taxable Income After 199
Federal Tax Rate
Tax Liability Available for Credits

8
9
10

Cumulative NOL Balance
Federal Tax Rate
Accum. Deferred Tax Asset

233,958
35%
81,885

Sep - Dec 2016

Jan - Jun 2017

Forecasted Taxable amounts per filing
Test Period
Jul 2017- Jun 2018
Jul - Dec 2018

2019

2020

23,997
(23,997)
35%
-

75,347
(75,347)
35%
-

48,183
(48,183)
35%
-

7,406
(7,406)
35%
-

57,999
(57,999)
35%
-

210,981
(21,027)
189,954
(10,955)
178,999
35%
62,650

209,962
35%
73,487

134,615
35%
47,115

86,432
35%
30,251

79,026
35%
27,659

21,027
35%
7,360

35%
-

Note: Taxable income amounts above are absent proposed increases to rates in this rate case filing.

Attachment to Response to KU AG-2 Question No. 1(d)
Page 1 of 1
Garrett

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 2
Responding Witness: Christopher M. Garrett
Q-2.

Refer to the response to AG-1-36.
a. Why does the Company show a debit-balance ADIT amount for a "Recycling
Credit Carryfoward"? Explain fully.
b. What sections of the tax code produced the Recycling Credit?
c. On which tax forms is the Recycling Credit claimed?
d. For which years and in what amounts was a Recycling credit claimed?
e. When does the Company expect to utilize the Recycling Credit Carryfoward?
Explain fully and provide projections.

A-2.
a. The Company was not able to utilize the credit on its state tax return. As a
result, the credit will be carryforward and applied to a future tax year. The
credit carryforward is an asset (debit balance to ADIT) that will reduce future
state taxes.
b. KRS 141.390.
c. Schedules QR – Qualified Research Facility Tax Credit and TCS – Tax Credit
Summary Schedule in Form 720 Kentucky Corporation Income Tax and
LLET Return.
d. The credit was claimed on the 2012 state tax return.
e. The Company filed amended state income tax returns in 2016 for 2012-2014
to utilize the credit. Upon the acceptance of the amended returns, the ADIT
balance was reversed in September.

 Response to AG-2 Question No. 3
Page 1 of 2
Garrett
KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 3
Responding Witness: Christopher M. Garrett
Q-3.

Refer to the response to AG-1-36.
a. Why does the Company show a debit-balance ADIT amount for a "Research
& Experimental Credit Carryfoward"? Explain fully.
b. What sections of the tax code produced the Research & Experimental Credit?
c. On which tax forms is the Research & Experimental Credit claimed?
d. For which years and in what amounts was a Research & Experimental credit
claimed?
e. When does the Company expect to utilize the Research & Experimental
Credit Carryfoward? Explain fully and provide projections.

A-3.
a. The Company was not able to utilize the credit on its federal tax returns due
to its Net Operating Losses (NOL). NOLs must be completely used before
credits can be utilized. The credit carryforward is an asset (debit balance to
ADIT) that will reduce future federal taxes.
b. I.R.C. Code Section 41 and 280C.
c. Form 6765 – Credit for Increasing Research Activities in Form 1120 U.S.
Corporation Income Tax Return.

 Response to AG-2 Question No. 3
Page 2 of 2
Garrett

d.

Annual
Amount
Actual – 2014
$191,611
Actual – 2015
$209,777
Projected – 2016
$200,000
Projected – 2017
$200,000
Projected (1/2 Year) – 2018 $100,000
13 Month Average – Forecast Period

Cumulative
Carryforward
$191,611
$401,388
$601,388
$801,388
$901,388
$762,530

e. The Company expects to use credits in 2021 absent rate case increases. See
attachment to response to Question No. 1d, line 7.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 4
Responding Witness: Christopher M. Garrett
Q-4.

Refer to the response to AG-1-36.
a. Why does the Company show a debit-balance ADIT amount for a "Solar
Credit Carryfoward"? Explain fully.
b. What sections of the tax code produced the Solar Credit?
c. On which tax forms is the Solar Credit claimed?
d. For which years and in what amounts was a Solar credit claimed?
e. When does the Company expect to utilize the Solar Credit Carryfoward?
Explain fully and provide projections.

A-4.
a. The Company was not able to utilize the credit on its federal tax returns due
to its Net Operating Losses (NOL). NOL must be completely used before
credits can be utilized. The credit carryforward is an asset (debit balance to
ADIT) that will reduce future federal taxes.
b. I.R.C. Code Section 48C.
c. Form 3468 – Investment Credit in Form 1120 U.S. Corporation Income Tax
Return.
d. 2016 - $4,000,000.
e. The Company expects to use credits in 2021 absent rate case increases. See
attachment to response to Question No. 1d, line 7.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 5
Responding Witness: Christopher M. Garrett
Q-5.

Refer to the response to AG-1-36.
a. Provide the detail for the Tax Repair Expensing amounts, including the
amounts of repairs deductions that were claimed in each year, and the income
tax rates that were applied to the annual Tax Repair Expensing amounts to
produce the ADIT amounts.

A-5.

a. See attached.

 Attachment to Response to KU AG-2 Question No. 5(a)
Page 1 of 1
Garrett
KENTUCKY UTILITIES COMPANY
Accumulated Deferred Taxes on Income
Tax Repair Expensing
As of June 30, 2018
Reg 1.167(l)-(h)(6)ii
(Dollars)
Timing Difference1
Projected 2016 Deduction
Projected 2017 Deduction
Projected 2018 Half-year Deduction

(30,000,000)
(30,000,000)
(15,000,000)

Tax Rate
38.9%
38.9%
38.9%

ADIT

Deferred Tax
(11,670,000)
(11,670,000)
(5,835,000)

(11,670,000)
(23,340,000)
(29,175,000)

Line
No.

Amount

1

Projected Accumulated Deferred Taxes at June 30, 2017

2

Projected Accumulated Deferred Taxes at June 30, 2018

3

Change in Accumulated Deferred Taxes for the forward year

4

Balance June 30, 2017

5

July 1-31, 2017

6

Monthly Increase/Decrease

(17,505,000)
(29,175,000)

Proration

(972,500)

335/365

August 1-31, 2017

(972,500)

7

September 1-30, 2017

8

$

(11,670,000)

$

(17,505,000)

Activity

(892,569)

(18,397,569)

304/365

(809,973)

(19,207,542)

(972,500)

274/365

(730,041)

(19,937,583)

October 1-31, 2017

(972,500)

243/365

(647,445)

(20,585,028)

9

November 1-30, 2017

(972,500)

213/365

(567,514)

(21,152,542)

10

December 1-31, 2017

(972,500)

182/365

(484,918)

(21,637,460)

11

January 1-31, 2018

(972,500)

151/365

(402,322)

(22,039,782)

12

February 1-28, 2018

(972,500)

123/365

(327,719)

(22,367,501)

13

March 1-31, 2018

(972,500)

92/365

(245,123)

(22,612,624)

14

April 1-30, 2018

(972,500)

62/365

(165,192)

(22,777,816)

15

May 1-31, 2018

(972,500)

31/365

(82,596)

(22,860,412)

16

June 1-30, 2018

(972,500)

1/365

(2,664)

(22,863,076)

17

13 Month Average with pro rata ending Deferred Taxes at June 30, 2018
1

$

$

$

The tax repairs expensing deduction is estimated to be $30 million per year based on prior year deductions.

$

(21,072,610)

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 6
Responding Witness: Valerie L. Scott
Q-6.

Refer to the response to AG-1-37.
a. Explain what is included in the "Other" category.
b. How much of the amounts in the "Other" category are expensed? Quantify
and include supporting calculations.
c. How much of the amounts in the "Other" category are capitalized? Quantify
and include supporting calculations.

A-6.
a. The charges shown in the “Other” category within the attachment to AG 1-37
include, but are not limited to; stores expense undistributed, other regulatory
assets, preliminary survey charges, accounts receivable and engineering
overheads. Certain amounts included in “Other” will ultimately be expensed
or capitalized, based on the nature of the transaction. However, due to the
system process in which these amounts are recorded, the labor portion of the
amount is not readily determinable once the process is completed.
b - c. See the response to part a.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 7
Responding Witness: Valerie L. Scott
Q-7.

Refer to the response to AG-1-37.
a. Why are the Expensed amounts for 2016 lower than 2015?
b. Why are the Capitalized amounts for 2016 higher than 2015?
c. Why are the Other Labor Cost amounts for 2016 lower than 2015?
d. Why is the Total Labor Cost for 2016 lower than 2015?

A-7.
a. The decrease in expensed amounts is primarily due to amounts capitalized for
work performed on an IT Customer Services project and the Green River
Plant closure.
b. The increase in capitalized amounts is primarily due to amounts capitalized
for work performed on an IT Customer Services project.
c. The decrease in other labor cost is primarily due to establishing a regulatory
asset for the Green River Plant closure in 2015 as approved in case 201400371.
d. See explanations for parts a-c.

 Response to AG-2 Question No. 8
Page 1 of 2
Blake
KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 8
Responding Witness: Kent W. Blake
Q-8.

Refer to the response to AG-1-49.
a. Does the Company's claimed revenue requirement include Labor Cost for
authorized but unfilled positions?
b. Is the $.224 million amount for KU's four vacant positions for payroll costs
only? If not, show a detailed breakout between payroll and benefit costs,
showing the amount for each type of benefit.
c. Is the $5.7 million amount for LG&E and KU Services Company's 34 vacant
positions for payroll costs only? If not, show a detailed breakout between
payroll and benefit costs, showing the amount for each type of benefit.
d. Show in detail how much LG&E and KU Services Company Labor Cost was
included in the claimed revenue requirement for the KU electric utility.
e. If possible, show the amounts identified in the response to part (d) by account.

A-8.
a. Yes, the Company’s filed forecast test period includes authorized positions
for the twelve month period ended June 30, 2018. This differs from the
positions filled as of December 31, 2016. The number of positions provided
in response to AG 1-49 represent the difference between the number of
employees for the respective companies as of December 31, 2016, and those
projected as of June 30, 2018.
b. No. See attached. In preparing this response, the Company noted an average
salary across all departments was used rather than using the average salary
for departments where the positions filled as of December 31, 2016 were
lower than those projected as of June 30, 2018. This raised the amount shown
in question 8(a) above, from $0.224 million to $0.409 million.
c. No. See attached. In preparing this response, the Company noted an average
salary across all departments was used rather than using the average salary

 Response to AG-2 Question No. 8
Page 2 of 2
Blake
for departments where the positions filled as of December 31, 2016 were
lower than those projected as of June 30, 2018. This lowered the amount
shown in question 8(c) above, from $5.7 million to $4.7
million.
d. As noted above, in responding to AG 1-49, the Companies provided the
difference in actual headcount as of December 31, 2016, and that projected as
of June 30, 2018, the end of the forecast test period. The estimated dollar
amounts in Question No. 8(b) and 8(c) above were developed based on
average pay rates by department multiplied by this difference in headcount
with applicable benefit burden adders applied, as noted above. This
represented total dollar costs as noted in the Company’s response to AG 149. Using the average expense percentage for departments with such
headcount differences, the dollar figures charged to expense above would be
$0.260 million for Question No. 8(b) and $3.7 million for Question No. 8(c).
Using the average company allocation for each department in Question No.
8(c), an estimated $2.0 million would be applied to KU.
e. It is not possible to show the amounts identified in the response to part (d) by
account, due to the manner in which the budget is prepared.

 Attachment to Response to AG-2 Question No. 8(b)
Page 1 of 1
Blake
Kentucky Utilities Company
Case No. 2016-00370
Comparing Actual Headcount at December 31, 2016 to Budgeted
Headcount at June 30, 2018
Kentucky Utilities
Number of Vacant Positions
Salary
Team Incentive Award
401(k) Match
Retirement Income
Group Life Insurance
LTD
Post Retirement Benefits
Post Employment Benefits
Workers Compensation
Dental
Medical
Other Misc
Payroll Taxes
Total Benefits and Taxes
Total

4
280,561
25,250
11,784
8,417
1,367
1,473
7,738
2,426
2,213
44,388
1,200
22,175
103,181
408,992

 Attachment to Response to AG-2 Question No. 8(c)
Page 1 of 1
Blake
Kentucky Utilities Company
Case No. 2016-00370
Comparing Actual Headcount at December 31, 2016 to Budgeted
Headcount at June 30, 2018
LG&E and KU
Services Company
Number of Vacant Positions
Salary
Team Incentive Award
401(k) Match
Retirement Income
Group Life Insurance
LTD
Post Retirement Benefits
Post Employment Benefits
Workers Compensation
Dental
Medical
Other Misc
Payroll Taxes
Total Benefits and Taxes
Total

34
3,348,176
301,336
140,623
100,445
16,312
17,578
59,806
19,075
2,579
18,809
377,298
10,200
262,187
1,024,912
4,674,424

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 9
Responding Witness: Daniel K. Arbough / Valerie L. Scott
Q-9.

Refer to the response to AG-1-50(e), Charges from LG&E and KU Services
Company.
a. Why are the charges from this affiliate projected to increase from $246.7
million for the base period to $319.8 million for the forecast period?
b. Identify and provide a copy of each advertisement and advertising campaign
for which LG&E and KU Services Company is charging cost to the utility.

A-9.
a. See the response to KIUC 1-38.
b. See attached.

 Attachment to Response to AG-2 Question No. 9(b)
Page 1 of 170
Scott

BYE BYE
LATE FEES.
My Notifications makes it easy to stay on top of your
bill by sending you a little reminder. To sign up:
• Register or sign in to My Account (my.lge-ku.com)
• Click on My Profile in the top right corner
• Choose how you'd like to be notified:
• Email

• Text
• Voice Call
• Choose when you'd like to be notified:
• When a new bill is available
• Five days before due date
• One day past due date

fC
. w:.
...1.1:~

v~
J~
~"

PPL companies

 Attachment to Response to AG-2 Question N0. 9(b)
Page 2 of 170
Scott

Setting the stage
for a bright future.

For years, the Maysviile Players have enriched the lives
and inspired the community of Maysville. As a sponsor,
we?re proud to play a supporting role in keeping the
spotlights on. Our energies go to serving you.

in

a PPL company

 

Attachment to Response to AG-2 Question No. 9(b)
Page 3 of 170
Scott

Helping power
the community
and the classroom.

From offering energy education programs to schoois
and supporting local libraries. providing serwce to our
community takes many forms. Empowering the next
generation is just one more way our energies go to
serving you.



a PPL company

 

 

Attachment to Response to AG-2 Question No. 9(b)
Page 4 of 170
Scott

0

ENERGY
SAVING WHEEL
\JGHTING/
Get the righ1' bulb.
Dimmer s\.vitches,
three-way

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other
specia lty

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 Attachment to Response to AG-2 Question No. 9(b)
Page 5 of 170
Scott

•* like Pag:e

LG&Ean.d KU
Publtshed by

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I

 Attachment to Response to AG-2 Question No. 9(b)
Page 6 of 170
Scott

ON
BACK 0
0
Q

Average temperature, usage
and charges compared to the
same time last year.
NEW! We're now including a
chart, so you can see how
your monthly usage compares
to p~vious months, as well
as for the same time period
the previous year.

l'aQe2

Account e 3000--0000-0001

Bill.ING PERIOD AT-A-GlJ\HCE

MONTHLY USAGE

El£Cllll: ~Wh)

Awg. Electric Charves per Day

A\'ll. Electric Usagt per Day (kWh)

55'
32
$4.0S
44.09

53'
32
$3.02

; Tax•& f988

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R8le Increase Fu School Tax (3.00'I< x $130.38)
Franchise Fee-lex!ngton-f.llyettt (4.tl0% x $130.33)
TolBI Taxet and Ftes

$4.19

~j·

3.91
5.22

'8.13

-

BIWNG INFORMATION

Rall Schedul9'
For aCOJll' al your rat& schedule, vlsft

Ill.I.IC

31.69

0
late Payment~
Late Chalye to be Assessed ~r Due Date

e -

QMQ"

._..

llllSYW LMTl'iAll

Aver.oge Temp~
Number or Dars Billed

fl)

~or call our Customer SeNice Department.

E) NEW! Daily average gives
you even more information,
like a daily average of your
monthly cost for energy.

fJD A breakdown of taxes and
fees included in your bill.

fD Billing Information gives you
relevant information about
your bill, account and service.

CUSTOMER SERVICE
lge-ku.com
800-981-0600

 Attachment to Response to AG-2 Question No. 9(b)
Page 7 of 170
Scott

TAKE
A LOOK

Say hello to your new KU bill! Your new and improved
bill is presented in a reader-friendly manner with charts
and messages designed to give you more information
so you can better manage your energy usage.
~

0
0
0

e
e
0

Vi .1
"-'.V..
Easy-to-find the
Amount Due and
Payment Due Date.

0

• PPL r:ompeny

01.tOATE

$139.76

5/18/16

Account Name:

Slnlce Addren:

BILLING SUMMARY
PrtViOIJs llalanc.
Payment(s) Rooeived

121.16
-121.16

Balin~ u of 4121/16
C.ment Elect~c Charge5
C\Jrrellt Taxes and Fees
Totil CUmnt Charges as ol 4121116
Totat Amount Due

Easy-to-read Billing
Summary that shows
your previous balance,
payments received and
your current charges.

4129/16 1or Acoount t 30CJ0.0000.0001

fJAOUNTOUE

Online Payments:
hlophonu I'll~:

S0.00
130.83

CUllomer Sentoe:

9.13
f138.Jli
$1at.76

Watk-tn Cenlllr.

JOllN SlllTH
100 Deer Crossing Way
l.EXINGTON KY

lge-1<11.com
(859) 25$-0394. preS$ 1-2·3
24 boor,: a day; $2.25 fee
j\!59) 255-0394
M~. 7am-7pm ET

e

1 QuallyStrHI
lexfllQIM, KY 40507

M-F, 8im-59Al ET
Neirt rel!! Wlll OQCUI 5119116 - 5121118 (tJeier Read Porticm 14)

The account name and
service address along
with ways to pay and
contact information
for Customer Service.
We also include the
date range for your
next meter reading.
A detailed breakdown
of your electric usage,
always shown in blue
with a lightning bolt.
An item-by-item
summary of your
current charges with
the total amount of the
charges in bold at the
bottom of the section.
Use the handy
payment stub at the
bottom of your bill if
you mail your payment.

CURRENT USAGE

L":::g ln~~aticn

Meter I l..2.00000

f Acl\Jal (R) kWll Reading on 4121/16
•

10109

Previous (A) kWh Reading on 3120/16

8698

OU-rent kWll \Jsage
Meter Multlpller

1411
1
1411

M.-,.d kWh Usage

CURRENT CHARGES

f

e

BSmllC

Basic Servi~ Charge

I

10.75
109.27
5.31
0.10

Energy Charge ($0.07744 ~ 1,411 kWh)
Ele<:lric DSM ($0.00376 x 1,411 kWh)
Fuel Adjustment ($0.00007 x 1,411 kWh)
Environmen!al Surcharge (3.950% x $125.43)
Home Energy Assistance Fund ChafGe
Total Charges

4.95
0.25
$130.63

I

·························· .................................................................................................................................. ...... ··•··············· ......................................................................................
PINB• •t1zlr• orly INt po~lon wlth y"'r Plyml!flt MaJ<e checlo! paylble to KU and wrtt• your 110D011nt numbef oo yoor chock.
Amount Ouc5/1 B/16
$139.76

:

Artc-rDucOatc P1 1 tlw:r.1·r~1r1f
WlnlelCare Donation:

fl~

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Account # 3000-0000-0001
S4ilvice AdOlliss: 100 Deer C/oo$il1g Way

Total Amourt Em:la6cd:
f92619D001 Sf
JOHN SMmt
I 00 DEERCAOSSING WAY
LEXINGTON, KY 40509·0000

a PPL company
PO 8ox9001954
KY 40290-1954

lOUIS'lll&,

n·l 11•1'1ll• 0t•ttlll11••t1°t111l• ...1ll0 ll1l'•t•11t11 1 t•t•H•t•

a2a3aaoaoaoooo10000000014 39sao oooa1397baaaaoaaaoooo2s

 Attachment to Response to AG-2 Question No. 9(b)
Page 8 of 170
Scott

PAYING

YOUR
DELINQUENT BALANCE
You may receive a new KU Bill before you've paid the Delinquent Amount
Due on your Disconnect Notice. A common mistake is to assume that you
now have until the due date on the new bill to pay your Delinquent Amount
Due. The Final Pay Date on yoor Disconnect Notice does not change upon
receipt of new bills. This is import.ant to understand to avoid disconnection
of service. Refer to the Payment Options section of your Disconnect Notice
fur ways to pay your delinquent balance.

CUSTOMER SERVICE
lge-ku.com

800-981-0600

 Attachment to Response to AG-2 Question No. 9(b)
Page 9 of 170
Scott

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SAME MESSAGE
NEW LOOK
It's still brown, and it still means urgent. KU's new Disconnection Notice is
designed so you can quickly see the important information you need to help
you avoid disconnection of service or find the assistance you need.

IMPORTANT
FEATURES
0

e

Easy-to-find Delinquent
Amount Due and Final
Pay Date to avoid
service disconnection.
Here you'll find the account
name and service address
along with ways to pay your bill
and contact information for
Customer Service it you have
questions or need assistance.

E) More details about Payment
Options and important
information about your
Final Pay Date.

0
0

0

Important infurmation about
reconnection of service if your
setvice is disconnected.
Here you'll find information
about community assistance
agencies that may be able
to help.
You can use the handy
payment stub at the bottom
of the bill if you choose to mail
your payment - just be sure it
will reach us by the due date
to avoid disconnection of
your service.

0

a PPL companv

Malled 5111116 llir Al:coont # 3000--0000-0001

JOH~ lllnll
100 Deer Crosslng
LEXINGTON KV

Way e
...

1

OnllnePaymenll:
Tllepllane P...,it:

IQHu.oom
(000) stHlOOO, praas 1·2-3

c.-..er Sel'lla:

(&ll) 91t1-0e00

Z4 ha111Ud8'J; $2~ ~

DISCONNECTION NOTICE

M·f. 71m-71)m ET
, Qiail1 S.eet

'I01¥-111 is pail ..... ~ llt --"'-Due ii llOt

lai9al. IO' 40507

..,..;..a lrt ... l'imr Dlllt. JOO" senke ... be Mlecl to
discaml!CGon.

IH, !lam-5pm ET

ReconneGtion: Your atnl:a wbl be ~nrecteO.Wltllln 24 l10urs
llftl!r.eriftcation of full PllYment o! 1118 Ultlnquent AmOtJnt lllle. A

reconnect ree ana a nrw or &!Cntonal <Epoolt wtm tie required as a
condltlen of reainno:ticn.

er~=.:==b~

.

dale, call our OJmmer SCMCt Cl8pu1menl You mst Ibo axnsct ttM!
ColNJlOnwNllh ct l<lntJd<y's Cllbinet ft.- F~llies and C1111dr111 II

1~00·372-2973 lllr I~ llll0111 ll1e a•eiallilily ot klall, 11811 ..-

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0 PAYMEtfl' OPTIOtlS
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on 11'18 bad: of Ihm nob.

Acccunt # 30IMHl(ll».IJ001
SeMc:e Address: 1oo Deer r.ross1~ Way

Tobll Amount &!closed:
"52000001 -

KtJ.

JOHN SMntt
100 Pt:lRalOSSINGWAV

LEXlNGTON, KV -C-0509·0000

e PPL company

PO Box 9001954
lou!Mle, IO' 4029!H 95"

02D30DDDD000001DOOODOOOlSSl3DOOD00155130000000000DOlO

 Attachment to Response to AG-2 Question No. 9(b)
Page 10 of 170
Scott

Planting a tree?

Building a fence?

Installing a swimming pool?
Know what's below.
Contact 811 before you dig.

You are required by state law to contact Kentucky

811 (dial 811 or online at 811now.com) before you
perform any excavation activity. Excavation is defined
as any activity that results in the movement of dirt.

Kentucky 811 will coordinate with member utilities
(LG&E and, in some areas, KU) to have them mark
the location of any underground natural gas and/or
electric lines in the area. The line location is performed
at no cost to you.
Once marked, you'll know what's below and
be able to dig safely. Different colored
markings or flags indicate what lies
beneath your dig site. Submit your
request at least two business
days before you dig to allow
time for the lines to be marked.

PPL companle$

 Attachment to Response to AG-2 Question No. 9(b)
Page 11 of 170
Scott

Pipeline marker information
Since pipelines are buried underground, pipeline
markers are used to help in their identification.
They are often found where a pipeline intersects a
street, highway or railway. Be aware of any pipeline
markers in your neighborhood. Markers provide the
approximate location of the pipelines, the type of
product transported, and the natural gas operator's
name and emergency number. Write this information
down in case of emergency.

Recognizing a suspected leak
Damage to pipelines may cause a leak. Report
any damage to our facilities, even if it appears to
be minor. In cases where physical damage is not
obvious, your senses of sight, smell and sound

will help you recognize a suspected leak:

Sight
Discolored vegetation, bubbling
in water or bl owing dust.

Sound
Hissing, whistling or roaring noise.

Smell
Unusual odor such as gasoline, oil,
sulfur or rotten egg smell.

If you suspect
a natural gas leak,
evacuate immediately and contact LG&E:

Dial 502-589-1444
(outside Louisville 800-331-7370)

then Press

1-1-1

PPL companies
For more information, visit:

lge-ku.comtgassafety

 Attachment to Response to AG-2 Question No. 9(b)
Page 12 of 170
Scott

Page 1of1

Connecting with us just got easier.
Try it today.

KU

file:///R:/Rate%20Case%20Support/2016%20KY%203rd%20round%20DR/AG%202-9(b)... 2/10/2017

 Attachment to Response to AG-2 Question N0. 9(b)
Page 13 of 170
Scott

Junior
Achlevement"'

JA BizTown?E? .
JA Finance Parky

 

Attachment to Response to AG-2 Question No. 9(b)
Page 14 of 170
Scott

The Campaign for JA BizTown and JA Finance Park

Dear Friends,

In a powerful program evaluation
published by the University of
Louisville's Department of Urban
and Public Affairs, JA Biz Town and
JA Finance Park programs get
results. Some statistics include:

Student success is central to Junior Achievement's mission to provide volunteerdriven learning that fosters workforce readiness, entrepreneurship and financial lit·
eracy. Under the guidance of local community volunteers, students apply real world
skills required in the 21st Century global marketplace. To date, JA of the Bluegrass
has harnessed the talents of 11 ,500 community business leaders to impact the
economic education of 430,000 students from 18 counties in Central Kentucky.
JA of the Bluegrass has impact!
The Campaign for JA BizTown and JA Finance Park provides the funds necessary to
fulfill our bold, strategic vision for the future. This fundraising effort will bring
the next level of experiential education to our children in the Bluegrass.

Increased Math Scores*
JABizTown:

0

5

10

15

201 2 41h grade scores
V$.
2013 5th grade scores

Building on over 50 years of service in Central Kentucky, we are confident that now
is the time for our organization to think BIG, be BOLD and share our VISION of
the future with the larger community. With a goal to raise $3 million in cash gifts,
our aspirations go beyond the financial component as we take this opportunity to
raise JA's profile and connections in our community as well. We embark upon this
endeavor not just focused on the immediate goal of building an exceptional physical
environment for learning but more importantly of building a sustainable organization
over the long-term with a legacy beyond our imagination.

+5.8o/o

Pro1iclenVOls1inguishe<1

0

5

10

20' 261h grade~~

Vs.

2013 7111 91ade score.<:

+13.1%

ProtlclenVDlstin;•lehed
~$ inclcaled by Jelfll'SOO Grully

Pl.flit Sdiools K >iro Sc:ms
a<cntucky Pm1nnaoce Rating far

In partnership with Fayette County Public Schools, we are working to apply our
experiential curriculum to core educational standards in the context of our local
economy. This learning experience--presented in a fun, hands-on atmospherewill inspire students to dream big about their future and understand what skills
they will need to reach their potential.

15

Consider joining us in this worthwhile endeavor, we look forward to creating our
vision together!

~~~
Lynn Hudgins
Presiden~

JA of the Bluegrass

Campaign Chair, JA BizTown and JA Rnance Park

~lional '.'r079SS)

Cover photo: In the JA BizTown experience students assume various roles, including CEO, CFO, utility
worker, restaurant owner, reporter, disc jockey. lawyer. and postal carrier.
2

I

Dl:r::Town It Fln nee Pa

I JAoftheBluegrsss

 Attachment to Response to AG-2 Question N0. 9(b)
Page 15 of 170
Scott

. I

\f

t?





I
a 

 

JA BizTowni

Imagine fifth grade students
discovering the real-life opportu-
nities available in the free en-
terprise system as they become
business operators, taxpayers,
and consumers in JA BizTown.

Most importantly, imagine
students who think that learning
1?me Mp We m3 . - been: math, econonnceJechlnol-
. ogy, seeial studies, and reading
WW and writing is fun!

 

JA ofthe Bluegrass I 3

Attachment to Response to AG-2 Question No. 9(b)
Page 16 of 170
Scott

"NEAR'L

1
\

OF TEENS SAID

THEY DON'T EXPECT
0/ FINANCIALLY
TO BE READY TO
SUPPORT

I 0THEMSELVES BY AGE 24.

nr 0I

~~!i

OF TEENS SAID THEY

'/no WOULD BE PREPARED
BVAGE27."

llJWlwtlos.id.er 2013

Why experiential learning? Nine out of ten teachers believe that experiential learning is
effective in getting students interested in higher education and careers.
(Source: JA Experiential Learning In Education Pol~
Throughout the semester, teachers may Invite business leaders to visit their classroom
to teach economic principles and reinforce class curricula through the lens of their own
professional experiences.
At the end of the set of lessons, elementary students will visit JA Blztown to apply
what they've learned in a simulated business community complete with storefronts, road·
ways and other civic amenities while middle school students visit JA Finance Park to
apply the knowledge they've learned in order to make smart personal and career-minded
decisions for the future.

Imagine willing volunteers jumping into this fun, real world atmosphere
to teach, armed with their enthusiasm and life experience.
-

"I learned that running a
business isn't just about making
money. You have to repay loans,
pay workers, and pay for
supplies!"
- 5th grade student
"Spend money on the things you
need first, and then spend on the
things you want"
- 5th grade sludent

4

I

ucTuwn & An nee P

-

JA BizTowne seNes upper elementary classes with operating "businesses" such as a
bank, City Hall, utilities center, realty office. restaurant, retail businesses and more.
Students discover the real-life opportunities available in the free enterprise system as
they become business operators, taxpayers and consumers for a day. The curriculum is
designed to correlate to Kentucky's Core Content for Assessment in Math, Social Studies,
and Practical Living while focusing on 21st century job skills.
JA Finance Park• provides a practical, hands-on personal budgeting simulation for
middle school students. The classroom curriculum is complemented by a visit to the Park,
where students will immerse themselves In a reality-based decision-making process
addressing individual and family budget considerations such as housing, transportation,
food, utilities, health care, investments, philanthropy and banking.
A day at JA BizTown or JA Rnance Parl< is always preceded by a series of lessons in the

dassroom.

I JA of the Bluegrass

 Attachment to Response to AG-2 Question No. 9(b)
Page 17 of 170
Scott

••
• ,• ,,,
•
• •
'
It!

I

• 1

 Attachment to Response to AG-2 Question No. 9(b)
Page 18 of 170
Scott

6

I

C!lz:Town & Finance Pnr1

I JAoftheBluegrass

 Attachment to Response to AG-2 Question No. 9(b)
Page 19 of 170
Scott

The health of the economy, and nation, depend on our workforce. The recent economic
recession caused a number of employers to downsize personnel. As the economy recovers,
former positions are being filled by individuals who possess more technical skills or greater
education. New labor market entrants are finding themselves unprepared to enter the current workforce and as a result companies are now struggling to fill open positions.

More than half of U.S. companies report a major challenge in recruiting nonmanagerial employees with the skiffs and knowledge needed. {Source: A Solution
to the Workforce Skills G~ The skills gap has been identified in both leadership and
executive-level skills (e.g. supervision, goal setting and motivation) or in basic skills \rncluding reading, writing, creative thinking, problem solving, honesty and adaptability). This skills
gap is expected to intensify as the Baby Boomers exit the workplace.

The JA BizTown/JA Finance Park
facility will be available to students
throughout Central Kentucky.
Counties located within a 30- to
90·mlle radius will be invited to
participate. This encompasses
more than 48 school districts.

2016/2017

50

Now is the time to invest in workplace learning and teaching the skllls needed in
the 21st Century. JA of tfle Bluegrass inspires and prepares young people to compete in

our global economy. We believe the outcomes of experiential learning via the JA Biztown
and JA Finance Park models are part of the solution to this challenge.

JA of the Bluegrass is uniquely positioned as a proven
and relevant provider of necessary skills development in
our community and in our country.
It's not about the dollars, It's about the impact When we reach our goal, JA of the
Bluegrass will increase not only the number of students who participate in our programs,
but will also add to the quality of their experience. Through greater invol\/ement from our
business leaders, our partners in the community will have an active role in delivering the
vital curriculum and outcomes that ultimately impact their bottom line.
As an organization, we aspire to improve our financial sustainability by strengthening
our endowment, increasing the income it generates and expanding philanthropic support
while also attending to our dual bottom line by leveraging our resources to create greater
mission impact.

ProJected Humber of Schools Served

"UK HealthCa1·e is excited to be

part ofJA BizTownf]A Finance
Parle. This innovative facility and
curriculum will give our students
the tools to make good financial
decisions and navigate the many
challenges they will face as contributing members to our communities
and our suciety. We 1.ook forward
to working with Junior Achievem ent on this imporlanl education
project."
- Michael Karpf. MD,
Execulive Vice President
for Health Affairs

JA of the Bluegrass

I

I 7

 Attachment to Response to AG-2 Question No. 9(b)
Page 20 of 170
Scott

Benefits of

"Keene/and and the equine
industry have a rich history in
the Bluegrass. Through our
participation in JA BizTown/
JA Finance Park, we look forward
to sharing with our young people
the industry's unique truditions
as well as showrn.sing our vast
economic impact throughout this
regi-on. Partnering with Junior
Achievement in this endeavor
gives us a wonderful opportunity
to develop the youth of our
community and enhance their
educational experience."
- Bill Thomason
President and CEO
Keeneland

Your financial support Is an investment in the future of our local, regional and national
economy. As a campaign supporter, you will be recognized as a leader in this

pace-setting project that will bring this currlcurum and experience to the smallest geographic area to be approved for this program by JA USA. In the facility,
donors will benefit from the physical interaction with the students as they soak up the
experience in this uniquely Bluegrass space.
Donors, you will also have the opportunity to incorporate your brand and values into the
applied curriculum. Not only will students recognize your brand, likewise teachers, parents
and community business leaders will be exposed to it while volunteering on-site. These
visits to the facifity create memories that last well beyond the daylong experience and
trickle home through take-away materials and conversations about their experiences over
the kitchen table.
As good stewards of your investment, we strive to tailor recognition that is most
meaningful to you. In general, we will acknowledge all donors through media and press
communications, our website and campaign report listings as well as events. Permanent
and termed naming opportunities are available.

'1A and the Fayette County Public Schools have enjoyed a strong partnership for many years.
Since its inception in 1963, over 430,000 ofour students have been inspired by the volunteers who
teach }A's curriculum.
To that end, we are pleased to have the opportunity to enhance our commitment to JA and its
mission of empowering students lo own their future economic success. ]A BizTown!JA Finance
Park is a very focused experience that we believe will be a "game-changer"for our students and
the entire Central Kenlucky community. Our kids will enjoy an opportunity ofa lifetime in
which they can truly make aduli decisions and actually learn first-hand how an economy works."
- Melissa Bacon, Board Chail; Fayette County Public Schools
8

I

IJ1zTown

e.

Flnnnce Pn

I JAoftheBluegras.s

 Attachment to Response to AG-2 Question No. 9(b)
Page 21 of 170
Scott

Early Investors

to Invest
Permanent Naming Opportunities (Solid Green Boxes)

V1 !

"'-Y8
a PPL compariv

KentuckyOne Health"
Solnt Joseph Hospi1"''
Saint Joseph East

Naming Opportunities (Wflite Boxes) for five years with option to renew.
70% directed to capital and 30% directed to operating.

(~~~~s_to_r_e_fr_on_t~$_1_0_0_,o_o_o~~~-)
(

Kiosk 75,000

meni

)

·- rships

$50,000

£.OOCAllONAL
l'OU~'DATION

MARKSBURY
FA MILY FOUhDA.rlOH

TOYOTA [~~=:.:

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HealthCare
LEX

Personalized opportunities are a

available.

Storefront funding options are either $100,000 for a five-year term with a right of first
refusal for $10,000 annual renewal, or $300,000 permanent storefront right for life of
the facility. Funding amounts do not include customized build out expenditures beyond
the standard model.

i E;.l
Individual Partners
Gary and Sheila Bello

Mike Scanlon
Andy Shea - Lexington Legends
JA of ltla Bluegrass

I

I 9

 Attachment to Response to AG-2 Question No. 9(b)
Page 22 of 170
Scott

JA BizTown/JA Finance Park will be a dual implementation facility-meaning that both programs will be housed in the
same structure-<Jptimizing our efforts to reach more students. Though the facility will have the look and feel of JA BizTown,
the curriculum will be changed to accommodate JA Rnance Park middle school students during certain weeks of the year.

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 Attachment to Response to AG-2 Question No. 9(b)
Page 23 of 170
Scott

Business Sectors for Storefronts

•w

Bank

•

City Hall

Media Center

Higher Education

Y Retail

Housing/Real Estate ~ Philanthropy

al- Distribution Center

'J Insurance

~

~ Equine Center

St Investments

1@1Restaurant

.. Television

Professional Offices

..., Transportation
~

Utilities

Health Care

...

>at.•

.

.

Scanlon Family
J>hil3nthropy

Center

Community Room

MARKSBURY
tA "'. lt.' ) OU tl O AOf lO ll

ENHY
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MAIN
ENTRANCE

JA Qf the Bluegrass

I

I 11

 Attachment to Response to AG-2 Question N0. 9(b)

JA of the Bluegrass Board of Directors
Tim Arth ur Alltech

Justin Badeau Forcht Bank

Lynda Commerce Lexington
Victoria Bianco Crowe Honrvath LLP

Brian Briley Davis H. Elliot Company
Cody Brown CMC, Inc.

Mac Crawford Crawford Builders

Sheri Evans Depp Lexmark

Greg Dixon Smart Recycling Management
Robert Duncan Jackson Kelly

Kelly M. Johns Stablemate Creative, LLC
Paul Johnston Blue a Company

Trevor Jones KY Historical Society

David Kidd PNC Bank

Lora Knight Home Builders Association of KY
Brad Lovell Keeneland

Patrick McGee Churchill McGee. Inc.

Eric Monday University of Kentucky
Daniel P. Murphy, Jr. UK College of Law
Wessley Perry UPS

David Hoyse Ransdell Roach 8c Royse PLLC
Todd Sallee 

James M. Schrader - Schrader Commercial
Properties, LLC

Dave Sevigny - DMD Data Systems

Andy Shea Lexington Legends

Ed Staten

Kevin Staton Blackhawk Mining

Robert Trimhle 

Woodford Webb ?The Webb Companies
Jordan Wilson 

Todd Ziegler - Republic Bank 8: Trust

Junior
Achlevement?i

JA BizToww
JA FEFIEW ca; Park?i

 

Page 24 of 170
Scott

Campaign for

JA Biz'lewnIJA Finance Park
Steering Committee
Ed Staten, Chair
David Kidd

Brad Lovell

David Royse

Mike Scanlon

Dave Sevigny

Andy Shea

Todd Ziegler

of the Bluegrass Staff

Hudgins - President

Hon Wigglesworth Senior Program Manager
Sheila tl'aughn Development Manager

Erin Warren Program Manager

Callie Tincher - Program Manager

For more information,
please contact Hudgins:
859-219-2423 office
859-333-6269 mobile
 hudgins@jatexington.org

Help us fultill our
hold, strategic
vision for the future.

Attachment to Response to AG-2 Question No. 9(b)
Page 25 of 170
Scott

BUSINESS
SERVICE CENTER
Customer Service for Kentucky Businesses

Business Service Center
Customer Service
for Kentucky Businesses
LG&E:
KU:

502-627-3313
859-367-1200
800·383·5582 (outside Lexington)

Hours of Operation:
Monday - Friday, 8 a.m. to 6 p.m. (Eastern Time)
Email:

bsc@lge-ku.com

I.Gt: Kl!
PPL companln

BSC_brochure.. May20l 6 2panel.indd 1

PPL companies

5127/2016 10:47:1SAM

I

 Attachment to Response to AG-2 Question No. 9(b)
Page 26 of 170
Scott

Interested? Register online at my.lge-ku.com. Be
sure to have a copy of your bill when registering, since
some information found on the bill is needed during the
registration process. User guides can be found at lge-ku.
com/ bsc.

Business Service Center
he Business Service Center provides quick,
accurate and courteous service to commercial and
industrial businesses. Utility-related matters, such
as billing questions and orders for new or changed
services, can be handled quickly by phone or email.

T

Online Services for Business Customers:
lge-ku.com/bsc
• Establish/cancel gas or electric services
• Review and pay bills
• Request summary billing, automatic banking, online
billing or a free energy audit
• View electric or gas rates

Property Managersjl.andlords
Property managers and landlords with multiple LG&E and/
or KU accounts can access enhanced online options by
registering online.
Landlords can register all of their
•·""- ... - ....
properties using a single email address ~~...
, ',.,,,f=S'
and can access the information online
=.\~... 'ff
at any time, day or night. Additional
£::= !;..:-::_
functionality includes the ability to:
• create or
update landlord
agreements;
• check status of your
registered accounts;
• update account information, including telephone
numbers and mailing addresses of multiple accounts;
• pay bills online; and
• submit "move-our or Mmove-in" requests.

--

SSC.J>rochure_MaY2016_2panel.lndd 2

LG&E

KU

820 w. Broadway
Louisville, KY 40202
502-627-3313

One Quality Street
Lexington, KY 40507
859-367-1200
(outside Lex1ngtan: 800-383-5582)

Questions & Answers
Q. What is the Business Service Center?
A. It's a customer service center just for business
customers. The Business Service Center (BSCl helps
business customers a number of ways - ranging from
fast phone responses to onsite support.
Q. When is the BSC open?
A. Normal hours of operation are 8 a.m. to 6 p.m.
(Eastern Time), Monday through Friday.
Q. What Is the best way to contact the BSC?
A. Phone: 502-627-3313 (LG&E)
859-367-1200 (KU)
or 800-383-5582 (KU outside Lexington)
Email: bsc@lge-ku.com. The email will be routed to
your provider.
Internet: lge-ku.com/ bsc. On this page, you select
your provider: KU or LG&E.

5/27/2016 10:47:17 AM

I

 Attachment to Response to AG-2 Question No. 9(b)
Page 27 of 170
Scott

WHEN IT COMES TD PROVIDING LO\J-C09T ENERGY,
WE'RE HRRD TD BEAT

-

The data shows that KU's average
rate is:

!.&.!..
·..

KU

MISSllURI

lftDIAftA

UHITtD SlRTtS

• B percent lower than Missouri
• 22 percent lower than Indiana
• 38 percent lower than the U.S.
• 44 percent lower than Ohio

OHIO

We work 24/7 to provide you with safe and reliable energy, at a
good value for your money. In fact, when it comes to cost, the
Edison Electric Institute reports that the KU service area's average
residential electric rate more than holds its own compared to
some of our neighboring states and even the U.S. as a whole.

And businesses take note, too.
Thanks in large part to low-cost
energy, Site Selection magazine ranked Kentucky third in the
nation in 2015 on its list of Top State Business Climates.
Rest assured that as we continue to invest and improve how
we produce and deliver energy, keeping costs low remains a
top priority.

9CAH ALERT: KEEPING AN EYE OUT FDR THE BRD GUYS
KU will NEVER call or email
you to demand payment or
ask you for a credit card
number or debit card number.
Unfortunately, some scammers
pose as KU representatives
and demand payment over
the phone or in person - and
even threaten to cut off
service if the payment is not
made. If you receive such a
call or email claiming to be

from us, DO NOT provide any information and report it to local
authorities. If you are in doubt, call us at 800-981-0600.
A representative will confirm your account st atus and let you
know if a paymerrt is due.
Also, be aware of possible scammers who may come to your door
claiming to be one of our employees. Our employees always wear
official badges with the KU logo. Also, request a second form of
identification and check to see if their vehicle features our logo.
Nothing is more important to us than your safety and your
comfort with our employees and the services we provide.

TD AVOID TME MURT, DON'T TURN THE DIRT ... UNTIL YOU CALL 811
Coming soon: National Call Before You Dig Day.
Held e very year on August 11 (8/11), it is a day set
aside to focus on the need to call 811 before you
turn any dirt for an outdoor home improvement or
repair project. The first and most important tool
for any such project is your phone. When you call
8 11 a few days before putting a shovel or spade
into the ground, it gives time for local utilities,
including KU, to mark any underground lines whether electric, cable or water - they have on

your property. And here's a scoop - they'll mark those
lines for FREE. Knowing where those lines are can save
you some big trouble. If you were to hit one while
digging, it could cause serious damage or, worse, a
serious injury.
If you live in an area where your KU service is not covered
by Ke ntucky 811, call us at 800-98 1-0600 to req uest to
have your underground electric lines marked.
If you are unsure, visit our website at lge-ku.com to find
out if you shou Id call us di rectly or can call 811.

Sign up for My Notifications and receive timely reminders about the due date of your bill by text, email and/or phone.
Visit my.lge-ku.com for more Information.

 Attachment to Response to AG-2 Question No. 9(b)
Page 28 of 170
Scott

FOR YOUR OLD FRIDGE DR FREEZER TJll9 DEA 19 APLEA9ER
-

It could be that you're ready for a big
energy-efficiency upgrade for your
kitchen. Maybe you plan to
replace some older appliances
]
that have just about
reached the end of their life
spans and simply are not
nearly as energy-efficient as
today's newer models. And if one
of those appliances ls a refrigerator or freezer, you should know
about our Fridge and Free:zer Recycling program.

r]

~

~

We'll pay you $50 for your old refrigerator or freezer, plus we'll
haul it away as long as it meets the following requirements:
•
•
•
•

It must be operational.
It must be full size.
It must be empty.
It must be accessible for removal.

That's all there is to it. So, it's the proverbial win-win. We'll give
you 50 bucks to help stock your new, more energy-efficient
refrigerator or freezer (or spend however you like) and take your
old energy-eating appliance away to recycle. You might say it's a
really cool deal. Call 800-356-5467 or visit lge-ku.com/recycle to
learn more.

YOU DON'T NEED AGl'9 TD FIND US WHENYOU'RE ON THE HORD
Since it's the middle of summer, you're probably a little more on
the go than at other times of the year. And that's one reason
we've made sure our website, lge-ku.com, fits your lifestyle your mobile lifestyle, that is. No need to be at your desk or carry
a laptop with you. Because our website Is optimized for your
mobile devices, you can use your tablet or phone to access
bill-paying information, to learn some energy-saving t ips or to
learn more about what we're doing to improve the infrastructure
and service we provide to you. On the road or at the pool, it's
just a few clicks away.

reminded - when your bill is available to view, five days before
it's due or one day past its due date. Sign up via your online
account (or easily create one at my.lge-ku.com).
So be as mobile as you want. We're right there when you
need us.

You can also use your device to sign up for My Notifications to
receive timely reminders about your monthly bill. You choose
whether you want to be notified by email, text, phone call or a
combination of all three. Plus, you tell us when you want to be

COOKINGUP RFEWSUGGESTIONS FOR COOLING DOWN THE KITCHEN
You're probably familiar with the old saying, "If you can't stand
the heat, get out of the kitchen." Well, since it's the middle of
summer, we're modifying that just a bit to say, "If you can't stand
the heat, keep it out of the kitchen." To help you do that, here are
a few tips for reducing heat and saving energy:
Refrigerators
• Locate your refrigerator away from the oven and other heatproducing appliances.
• Keep the refrigerator full, but don't overstuff it.
• Partially thaw food in the fridge before putting it in the oven.
• Vacuum the condenser coils to remove dust.
Dishwashers
• Use the energy-saving or light-wash cycle.
• Use the "no heat" setting if there is one; otherwise, turn off
after final rinse and open the door to let dishes dry.
Cooking
•
•
•
•

Use your microwave or slow cooker during hot weather.
Keep the stove's burners and reflectors dean.
Cover pans and match the size of the pan to the burner.
Cook double batches and freeze the extra for a later meal.

KU

Contact
Information

By Phone
800-981-0600
Mond ay-Friday
7 a m.-7 p.m. {Eastern Time)

Seti-Service by touch-tone phone
or web:

Slow Cooker Sweet and Sour Chicken
(Courtesy: myrecipes.com}

Ingredients
1 cup chopped onion
1/3 cup sugar
1/3 cup ketchup
1/4 cup orange juice
3 tbsp . cornstarch
3 tbsp . cider vinegar
2 tbsp. soy sauce
1 tbsp. grated peeled fTesh ginger
1 lb. skinless, boneless chicken thighs, cut into 1-inch pieces
2 8-oz. cans pineapple chunks in juice, drained
1 large green bell pepper, cut into 3/4-inch pieces
1 large red bell pepper, cut into 3/4-inch pieces
3 cups cooked white rice

Preparation
Combine all ingredients except t he rice in a slow cooker.
Cook on LOW for 6 hours or HIGH for 4 hours. Serve over
prepared rice.

''
I

·---~--------------~-----------------------------·

Business Service Center
859 -367-1200
800-383-5582
Monday-Friday
8 a.m - 6 p .m. (Eastern Time)
In-Person

Anytime day or n ight

Customer Service Walk· in Centers

For Hearing· or Speech-Impaired
Dial 711

Monday- Friday
9 a. rn.- 5 p.m. (Eastern Tim e)
Lexington Office: 8 oi.m. - 5 p.m. (ET)

Editor
Cheryl.Williams@lgo-ku .com
Visit our website:
lge-ku.com

namm ~

••

Like us on Facebook (facebook.com/lgeku) and follow us on Twitter (@lgeku) and lnstagram (lge_ku).

 Attachment to Response to AG-2 Question No. 9(b)
Page 29 of 170
Scott

TRKE RFEW MINUTES FOR 9AFETY'9 9AkE
June is National Safety Month.
So, here are a few simple things
to make note of around your
home to help ensure the safety
of you and your family:
• Test the Ground Fault Circuit
Interrupters (GFCI) and Arc
Fault Circuit Interrupters
(AFCI) on electrical outlets.
Pressing "test" should cut
off power to the outlet.
Press "reset" to
restore power.

• Check furnace/ air conditioner
filters. If they are dirty, clean them
or replace with new ones.
• Avoid leaving engines running in
attached garages. This includes
not only cars, but also other
things with internal combustion
engines, such as lawn mowers.
• Avoid overloading outlets with
too many appliance plugs.

Safety is a core value at KU. We want to do what we can to
promote good safety habits and reduce the likelihood of
accidents. Check out the National Safety Council's website at
• Check appliance wires and cords for damage. Reduce the risk
nsc.org for more safety tips.
of fire by replacing any that are frayed.

WHEN IT COMES TD \JA9TING ENERGY, YOUR WRSHING MRCHINE
CRN BE RGITRTING
When your clothes are in the washer getting a good soaking, your
bank account doesn't need to take a soaking, too. These tips will
cut down on laundry energy use and let you keep more of your
hard-earned money:

• If your machine has one, use the
suds-saving feature for lightly soiled
clothes. You can reuse the wash water
when you follow with a second load.

• Wash clothes in cold water whenever you can. 90 percent of
the energy used by washing machines goes to heating water.

If you're in the market for a new washing
machine, buy an ENERGY STAR"' certified
model. This type of washing machine uses
about half the water and electricity of
older models, plus you can apply for a
$75 rebate through our Home Energy
Rebates Program. Visit lge-ku.com/rebate
to learn more.

• Reduce the temperature on your water heater to save energy
when you do have to wash in hot or warm water.
• Wash full loads. Whether you fill up the machine or wash
a single item, older machines use about the same amount
of water.

YOU MIGHT BE 9URPRl9ED WHRT YOU FIND WHEN YOU GIVE YOUR
HOUSE RN ENERGY CHECKUP
You may already be
doing a number of
things to make your
home more energy
efficient, but it's a
near certainty there
are even more steps
you can take to
reduce your energy
usage - and,

therefore, the amount you spend o n energy. The first step is to
determine which parts of your home use the most energy.
And the quickest and easiest way to do that is to use our Online
Home Energy Analysis. In just a few minutes you'll learn how to
save energy and money.
To get started, go to lge-ku.com/analysis and then follow the
instructions. The Online Home Energy Analysis is available for
customers who have at least one year of active service in their
current home.

Sign up for My Notifications and receive timely reminders about the due dote of your bill by text, email and/or phone.
Visit my.lge-ku.com for more information.

 Attachment to Response to AG-2 Question No. 9(b)
Page 30 of 170
Scott

"OUR ENERGY HA TTER9" SERIES PROFILES PROJECTS THRT
ENHRNCE SERVICE, RELIRBILITY RHO OUR ENVIRONMENTAL COMMITMENT
Providing safe, reliable, low-cost energy for all our customers is
part of how our energies go to serving you. We are constantly
striving to make sure we deliver on that promise. And one way
we do so is by making investments in our infrastructure. Our
large-scale solar facility near Harrodsburg is an example of one
s uch investment.
We Invite you to visit our website at lge-ku.com/investments and
check out new videos - titled "Our Energy Matters" -

highlighting investments we are making and the employees who
are working on them to ensure we meet the energy demands of
the future. From infrastructure improvements supporting
continued environmental compliance to major projects that
further enhance safety and reliability for our customers, our
employees are dedicated to keeping the lights on - now and for
generations to come.

GREEN ENERGY: RNEHPO\JERING CHOICE
Every time you flip a switch,
brew a pot of coffee or adjust
your thermostat, electricity is
drawn from the "grid."
This grid is made up of
electricity created from a
variety of fuel sources,
including coal, natural gas and
renewables like wind, solar
and hydroelectric. While the
majority of electricity
generated in Kentucky comes
from fossil fuel sources, there
is a way to directly influence renewable energy in our region.
It's called the Green Energy program, and here's how it works.
For $5 a month, you can directly support the growth and
long-term viability of regional renewable energy operators and
the broader renewa ble energy indu.s try. The Green Energy
program will use your monetary contribution to purchase

Renewable Energy Certificates (RECs) on your behalf. One REC
represents the property rights to the environmental, social and
other nonpower benefits of 1,000 kilowatt hovrs (kWh} of
renewable electricity. The Green Energy program provides an
easy way for you to obtain RE Cs and their associated benefits,
as well as show your support for renewable generators and
the industry.
Renewable energy has significant up-front costs, and voluntary
purchases of Renewable Energy Certificates play an essential
role in helping operators recover these costs more quickly,
encouraging reinvestment in the renewable energy economy.
The program is completely self-funded, wherein every dollar you
contribute goes directly toward purchasing RECs or promoting
the program. We work hard to get the most value out of your
contributions, and 2015 was no exception. On average, every
$5 contributed purchased 1.8 RECs. So what are you waiting for?
Call us or visit our website at lge-ku.com/green today to
learn more.

WHETHER YOU'RE HOME DR RWRY, IT'S 9TILL EA9Y TO PAY
If you're planning to be on the go this summer, you can easily pay
your KU bill without worry while you are away. Just use one of the
options below to help simplify your life:
• Auto Pay - your monthly payment will be automatically
deducted from your bank account on the payment due date.
You will continue to receive a monthly billing statement with
ample time to verify the information and record the amount
and date of the automatic withdrawal. Simply sign in to your
online account - or easily create one - at my.lge-ku.com or
call us at 800-981-0600.
• Online payment - through your account at my.lge-ku.com
you can easily and securely pay with an electronic check,
credit card or debit card. And, remember, we're completely
mobile, so you can access our website and your account on

KU

Contact
Information

By Phone
800-981-0600

Monday- Friday
7 a.m.- 7 p.m. (Eastern Time)

payment processing fee, select
the "electronic check" option. All other online and pay-by-phone
options are subject to a fee charged by the third-party vendor
that processes those payments for us.

Business Se rvice Center
859-367 -1200
800-383-5582

Ed itor
Chery:.w :lliams@lge-ku.com

Monday-Friday
8 a.m.-6 p.m. (Eastern Time)

lge-ku.com

Self-Service by touch-tone phone
or web:

In-Person

Customer Service Walk-in Centers

For Hearing- or Speech-Impaired

Monday-Frid ay
9 ;:i.m.-5 p.m. (Eastern Time)
Lexington O ffice: 8 a.m.-5 p.m. (ET)

. . l .- ........ ~...,,.

• r·

NOTE: To avoid the online

A;lytime day or night
Dial 711

'•

any of your mobile devices.
• Pay by phone - our
automated bill payment
system is available 24 hours
a day. Call us and press
1-2-3 to make a payment
with an electronic check,
credit card or debit card.

· Like .us

_ •·.

Visit our website:

namm &!a

••

on Facebook (facebook.com/lgeku) and follow U5 on Twitter (@lgeku) and Instag ram (lge_ku).

YL.1'3~=,:...···.:

 Attachment to Response to AG-2 Question No. 9(b)
Page 31 of 170
Scott

~

·1.
YOUR NEW BILL: MORE INFDRMRTIVE, HORE l-IELl'FUL
It's here! By now, you've most likely
spending on energy each day.
seen your new, more informative.
It's all info you can use - in a new
KU billing statement, which was
format - to help you manage your
previewed in last month's issue of
energy usage, especially when you
Power Source. The new design
combine the new features and
comes after extensive research and
information with our energy-efficiency
feedback from customers like you
tips and programs.
- through focus groups and an online
Be sure to learn more about your
customer panel.
new bill by visiting our website at
The new bill has lots of helpful
lge-ku.com/mynewbill and reading
features, like an easy-to-read chart showing how your energy
the insert included with this
usage over the past 13 months compares on a _month-to-month
month's statement.
and yearly basis. You'll even find the average amount you're

BE 9HART RND BE 9AFE AROUND ELECTRICITY
Electricity has the power to keep us out of the dark, keep our
computers running and make sure our appliances come to life
when we need them. But it also has the power to cause harm including serious injury and house fires - if we don't respect it or
don't practice good safety habits. Here are a few tips to make
sure using electricity remains a positive experience:

• Water is a no·no - do not touch light switches, appliances or
anything that uses electricity if your hands are wet or you are
standing on a wet surface.
• Plugs only, please - do not stick metal objects into outlets.
If there are small children in the house, use safety caps in
outlets that are not being used.

• It's getting too crowded - do not plug multiple appliances
into a single outlet.
• Don't be a "frayed" to be safe - cracked or frayed wires
can be a fire risk. Replace any you find.
It's always a good rule of thumb to stay away from power lines
when working or playing outdoors. If you are carrying a tall
ladder, hold it parallel to the ground and make sure to check for
overhead power lines before setting it upright

NEVER let children climb or play
around trees close to power lines.
NEVER touch a downed power line
- always assume it is energized. If you
see a downed power line, call us at
800-981-0600.
.
Bonus safety tip: if someone who
comes to your door identifies himself
or herself as one of our employees,
ask to see a company identification
card, which will include the
employee's name and photo and the
company logo. Also check for a
company logo on the vehicle they're
driving. Still not sure? Call us, and we
can confirm if the person is one of our
employees. And be mindful of scams
related to your bill. Don't hesitate to
call us and the police if you ever
receive a phone call demanding payment of your KU bill.
Your safety and peace of mind are among our top priorities.

HELP US HELP YOU
~

You may not think about your meter too
'""\. often, but it's important for our
"~.~ technicians to have easy access to it so
,.
they can get accurate monthly
readings. Basically there should be at
least six feet of clearance in front of
the meter and two feet on either side.
For purposes of getting an accurate
reading, meters must be accessible
Monday through Friday between the
hours of 8 a.m. and 5 p.m. In addition, our

technicians must have access any time to deal with any type of
emergency - such as a power outage - to assess and repair
equipment damage or to address a safety hazard.
Please do not block access to your meter when you do any
landscaping or outdoor building projects. If you are planning
any such projects in the vicinity of your meter, call us at
800-981-0600, and we'll work with you to make sure meter
access is maintained. View the customer handbook on
lge-ku.com to learn more about meter access and
clearance restrictions.

Sign up for My Notifications and receive timely reminders about the due date of your bill by text, email and/or phone.
Visit my.lge-ku.com for more information.

 Attachment to Response to AG-2 Question No. 9(b)
Page 32 of 170
Scott

TEAMING WITM YOU TD KEEP THE POWER FLOWING
Getting electricity safely into your home so you have the power
you and your family need for daily life is a shared responsibility.
When it comes to maintaining the electrical connection that
brings the power into your home, some of it is our job and some
of it is yours. The accompanying diagram shows which items
custo"'9rs are responslble for:

If repairs are needed to any of these items, call us at
800-98 1-0600. We'll send a crew to make the repairs.
Transformers for underground service are provided by KU, but
installed by the customer. Customers are also responsible for the
wiring from the transformer to the masthead.

1. Weatherhead/masthead - t he vertical pipe-like structure
attached to the top of the meter box.

8CUSTOMER

2. Meter base - the box and the wiring inside, as well as the
meter socket.

\~

~

~.,ip;f...,:;··"'"-"
•"1'1', .I'Q
::o;;;;oeo....,.e-..,cz.-...

\<JI
-.

3. Cables or other items that secure the masthead and/or box

_-_,;

to your home.
4. The attachment point (eyebolt, etc.) that secures the electric
service drop.
If any of these items become damaged, you will need to call a
licensed electrician to make the necessary repairs.

..,._ QCUSTOMER

KU is responsible for:

• The service drop - this is the cable from the utility pole to
your home.

E) CUSTOMER-..

• The meter - the glass-enclosed meter inside the meter box.

~

• The electric lines within the right of way.
• The utility poles and transformers.

'

fl CUSTOMER

CA9M IN MAND RND HELP DEMAND
Heat and humidity are right around
the corner. So, of course, during this
"peak energy demand" season, air
conditioners will be running ... a lot.
To meet energy demand in the most
efficient and cost-effective way
possible, we're asking you to help
by signing up for our Demand
Conservation program ... and you'll
receive up to a $5 monthly credit on
your KU bill for the months of June,
July, August and September.
Once you sign up, a load-control
device is installed on your home
and connected to your central air
conditioning unit or heat pump.
On select peak energy demand
days, the device cycles the

KU

Contact
Information

compressor on and off for just a few minutes at a time, typically
between the hours of 2 p.m. and 6 p.m. when energy demand is
at its highest. While the compressor is off, your home's air
conditioner fan can continue to run, circulating the cool air
already in your home. Most customers feel little-to-no difference
in their homes' temperatures. We are limited to a maximum of 20
cycle events per summer - and we will not cycle on weekends or
holidays unless there is an extreme system emergency.
ff you are already a Demand Conservation participant
thank you for your support, and enjoy those summer energy
bill credits!

More than 170,000 customers are already part of the program.
If you haven't signed up yet, please visit lge-ku.com/dc or call
800-356-5467 to sign up today.

By Phone

Busineu Service Cente r

Editor

800-981-0600
Monday- Friday

859-367-1 200
800-383-5582
Monday· -Friday
8 a.m.-6 p.m. {Easte rn Tim e)

Chcryl.W illiams@lge-ku.com

Visit our website:

In-Person

ncanm ~

7 a .m.- 7 p.m. (Eastern Time)
Self-Service by 1ouch-1one phone
or web:
Anylimo;: d<iy o r

night

For Hearing- or Speech-Impaired
Di al 711

Customer Service Walk-in Cen1e rs
Monday- Friday
9 a.m.- 5 p.m. (Eastern Time)
Lexington Office: 8 a.m .-~ p.m. (c T)

ige-ku.com

••

Like us on Facebook (facebook.com/lgeku) and follow us on Twitter (@lgeku) and lnstagram (lge_ku).

 Attachment to Response to AG-2 Question No. 9(b)
Page 33 of 170
Scott

Picturesque and world-famous horse farms, the bourbon
industry, beautiful state parks and a little horse race
every spring. (Maybe you've heard of it.) These are some
of the things that have brought national accolades to
Kentucky and some of the main reasons people love
calling the Bluegrass State home.

However, a lesser-known fact helps contribute to a higher
quality of life and business-friendly climate: electric rates
that are among the lowest in the nation and compare
quite favorably to surrounding states.

HOW KU'S ELECTRIC RRTES STRCK UP
According to data from the Edison Electric Institute, the KU
service area's average residential electric rate shines compared
to the U.S. average and is favorable to neighboring states.
Here's how the average residential electric rates compare to the
averages of neighboring states and the U.S. as a whole.

KU's rates are:
• 22 percent lower than o ur neighbor to the north.
• 44 percent lower than the Buckeye State.
• 8 percent lower than the Show-Me State.
• 38 percent lower than the national average.

22%LOWER

INDIRNR

KU

44% LDWIR

OHIO

KU

8'/oLOWER

MISSOURI

KU

38% lOWER

UNITED

KU

STATES
Sign up for My Notifications and receive timely reminders about the due date of your bill by text, email and/or phone.
Visit my.lge-ku.com for more information.

 Attachment to Response to AG-2 Question No. 9(b)
Page 34 of 170
Scott

BUSINESS IS JUST EASIER HERE
According to Site Selection magazine, utility
infrastructure also makes powering businesses easier.
In fact, it's among the top four criteria considered by
corporate real estate executives when deciding where
to locate or expand projects, according to an October
2015 Site Selection survey.
Findings show this factor ranks higher than the criteria
of land/building prices and supply. ease of permitting
and regulatory procedures and availability of
incentives. The survey's conclusions bode well for
KU's service area. Numerous projects are underway to
enhance the safety and reliability of the area's electric
systems, as well as further reduce emissions from
electric generation.

DID YOU KNOW?
Kentucky is ranked

Site Selection

third in Site Selection's

magazine's annual

2015 Top State

Governor's Cup

Business Climates."

ranking has placed
Kentucky among the
top 15 states for the
last five years in

Kentucky's three largest

In 2015, 43 new

reached a record

cities (Louisville,

companies and 420

$27.5 billion last year,

Lexington and Bowling

expansion projects

with projects and

Green) all ranked

were announced,

services going to nearly

among Forbes' Best

resulting in more than

200 countries across

Places for Business.

Exports from Kentucky

a row

16,000 jobs and
$5.1 billion in

the globe.

investment.

for new and expanded
industrial activity.

•Georgia placed first; North Carolina was second.

KU
Contact
Information

By Phone
800-981-0¢00
Monday-Friday
7 a.m.-7 p.m. (Eastern Time)

Self-Service by touch-tone phone
or web:
Anytime day or night
For Hearing· or Speech-Impaired
Dial 711

Business Service Center
859-367-1200
800-383-5582

Monday-Friday
8 a.m.-6 p.m. (Eastern Time)

Editor
Cheryl.Williams@lge-ku.com
Visit our website:
ige ku.com

ln·Person

Customer Service Walk-in Centers
Monday-Friday
9 a.m.-S p.m . (Eastern Time)
Lexington Office: 8 a.m.-S p.m. (ET)

Like us on Facebook (facebook.com/lgeku), and follow us on Twitter (@lgeku) and lnstagram {lge_ku).

 Attachment to Response to AG-2 Question No. 9(b)
Page 35 of 170
Scott

Received On-Site Analysis
of over
homes

Installed more than

2,000 advanced meters

12,000

Saved

Recycled more than

37,000 refrigerators

Earned more than

$9 million in rebates

830,000

and freezers

for business facility upgrades

megawatt hours
Weatherized approximately

14,000 homes

0

through the WeCare Program

Installed over

170,000

Demand Conservation switches,
earning more than

$37 million

of energy which is
equivalent to powering

OQO h

70 ' for a yearomes
1

~--

Performed more than

29,000 Online
Home Energy Analyses

I~ I $11Earn~million

more tMn

in rebates for
high-efficiency appliances and products

in energy bill credits
Program enrollment data is representative of January 2008 to April 2016.
'Assumes average residential energy usage of 12, 000 kilowatt hours per year.
2Totals reflect the number of LG&E and KU residential customers participating in each prog1am.

 Attachment to Response to AG-2 Question No. 9(b)
Page 36 of 170
Scott

ENERGY EFFICIENCY PROGRAMS
FOR YOUR HOME
Advanced Meter Service provides detailed information
that helps give you a better understanding of electricity
usage in your home. This voluntary service comes at
no additional cost.
Demand Conservation helps manage the energy needs
of the entire community during peak electricity demand
days from June through September. A device is placed
between your home and connected to your central air
conditioner or heat pump that allows us to safely cycle it
off and on for brief periods - but only when absolutely
necessary to control the community's summer energy
demand. We'll credit your summer energy bills up to $5
per device for each summer month.
The Fridge and Freezer Recycling program helps you
haul away and properly recycle your old, inefficient
(but still working) refrigerators and freezers. In return,
you receive $50 per recycled appliance.

The Online and On-Site Home Energy Analysis programs
help you identify ways to reduce energy use and make
energy-saving improvements around your home.

• Online Analysis - Answer a few questions about your
home and a customized list of tips is generated.
This program is offered at no additional cost.
• On-Site Analysis - For a one-time fee of $25, you'll
receive an on-site home inspection with a certified
energy analyst. After the visit, a customized report will
help you identify areas for improvement in your home
and help you qualify for monetary incentives.
Home Energy Rebates from $50 to $750 are
available when you purchase qualifying ENERGY STARli<
certified appliances, HVAC systems, window film and
high-efficiency replacement windows. If you're planning
to make upgrades in any of these areas, this program
can help you offset the costs.
WeCare (Weatherization, Conservation Advice and
Recycling Energy) provides education and weatherization
for income-eligible customers. Visit our website for
eligibility details.
Visit lge-ku.com/savingenergy for more details and
eligibility requirements, plus information on ways your
business can save too. Click Savings Finder for an easy
way to get started!

 Attachment to Response to AG-2 Question No. 9(b)
Page 37 of 170
Scott

major Powerlines eNewsletter - Spling 2016

Page 1 of3

A f'ee electronic newsletter from William D:Orio.

Trouble viewing? View Online.

0

·' ·.· ·LIN ES

newsletter

Des igned to energize businesses.

Spring 2076

Take a look at our online Powerlines newsletter. We hope it provides
you with useful news and information to help you improve
your performance.
We are dedicated to excellence and ready to assist you with your
particu lar needs. Please let us know if you have any questions or
comments about this issue of Powerlines or any other issue. We
remain committed to providing you with safe, reliable service; an
exceptional customer experience; and the best value for your
energy dollar.
William DiOrio
Account Manager

Online Account Management

Access your usagP history in graph or table for'Tlat.

Major investment planned to meet environmental
requirements
Work set to begin this year

http://us4.campaign-archive2.com/?u=8e651 daeefl d0e0732 l 5ac3 b5 &id=73 6217e2fl&e=3... 2/10/2017

 Attachment to Response to AG-2 Question No. 9(b)
Page 38 of 170
Scott

major Powerlines eNewsletter- Spring 2016

Page 2 of3

Read more

Healthy growth in new business and expansions
Announcements show continued economic growth
Read more

A construction update
Major projects help reduce emissions
Read more

Moving closer to solar offering for busin·ess and
industrial customers
RFP issued for solar design and construction
Read more

Construction underway on solar facility
Tapping into the power of the sun
Read more

Fast and simple power outage reporting: just text us
It's easier than ever to tell us when your power goes out
Read more

Providing power beyond electricity
Employee giving benefits communit ies
Read more

http://us4.campaign-archive2.com/?u=8e651 daeefl d0e0732 l 5ac3 b5&id=73 6217e2f7&e=3... 2/1 0/201 7

 Attachment to Response to AG-2 Question No. 9(b)
Page 39 of 170
Scott

major Powerlines eNewsletter - Spring 2016

Page 3 of3

I want to FORWARD THIS EMAIL to

Subscribe

a friend or colleague.

I UnsubscriQe I ~te Ema.ll I privacy Policy I Con Lael us

PPL c:Gq1111les
Email sent by LG&E and KU - 220 Wesc Main Street. Louisville, KY 40202

http://us4.campaign-archive2.com/?u=8e651 daeefl d0e073215ac3b5&id=736217e2f7&e=3 ... 2/10/2017

 Attachment to Response to AG-2 Question No. 9(b)
Page 40 of 170
Scott

economic Powerlines eNewsletter - Spring 2016

A free elec:rcnic newslecter rrom our Economic Oeve'opment tea:n.

Page 1of3

Trouble viewing? View Online.

0

.· . .· LI NES
Designed to energize businesses.

00

newsletter
Spring 2076

Take a look at our online Powerlines newsletter. We hope it provides
you with useful news and information to help you improve
your performance.
We are dedicated to excellence and ready to assist you wit h your
part icu lar needs. Please let us know if you have any quest ions or
comments about this issue of Powerlines or any other issue. We
remain committed to providing you with safe, reliable service; an
exceptional customer experience; and the best va lue for your
energy dollar.

http ://us4.carnpaign-archive l .com/?u=8e651 daeefl d0e073 215ac3 b5&id=970812 5a6e&e=...

2/10/2017

 Attachment to Response to AG-2 Question No. 9(b)
Page 41 of 170
Scott

economic Powerlines eNewsletter - Spring 2016

Online Account Management

Page 2of3

Access your usage history in g'apt-i or tahle forma;..

Major investment planned to meet environmental
requirements
Work set to begin this year
Read more

A construction update
Major projects help reduce emissions
Read more

Moving closer to solar offering for business and
industrial customers
RFP issued for solar design and construction
Read more

Construction underway on solar facility
Tapping into th e power of the sun
Read m ore

Rebates available for LEED-certified new construction
Significant cash is available for upgrades
Read more

Conserve energy with demand-side management options
Reduce energy demand, increase efficiency
Read more

http ://us4. campaign-archive l .com/?u=8e651 daeefl d0e073 215 ac3 b5&id=9708125a6e&e=...

2/10/2017

 Attachment to Response to AG-2 Question No. 9(b)
Page 42 of 170
Scott

economic Powerlines eNewsletter - Spring 2016

Page 3of3

Fast and simple power outage reporting: just text us
It's easier than ever to tell us when your power goes out
Read more

It's safe to say we're sticklers for safety
A little time can save big headaches
Read more

Providing power beyond electricity
Employee giving benefits communities
Read more

I want to FORWARD THIS EMl\!L to a friend or colleague.

Subscribe I Uosubscribe I Ur date Email I Privacy Policy I Contact us
_ PPL CClmlMlileti

Emai sent by LG&E and KU - 220 West Main Street, Louisville, KY 40202

http://us4.campaign-archivel.com/?u=8e65 l daeefl d0e073215ac3b5&id=9708125a6e&e=...

2/10/2017

 Attachment to Response to AG-2 Question No. 9(b)
Page 43 of 170
Scott

economic Powerlines eNewsletter- Summer 2016

A free electronic nP.wslecter from our Econorn:c

~Jevelupment

Page 1of3

team.

Trouble viewing? View Online.

O O QO

·

LIN ES

Designed to energize businesses.

newsletter
Summer 2076

Take a look at our online Power/Ines newsletter. We hope it provides
you with useful news and information to help you improve
your performance.
We are dedicated to excellence and ready to assist you with your
particular needs. Please let us know if you have any questions or
comments about this issue of Powerlines or any other issue. We
remain committed to providing you with safe, reliable service; an
exceptional customer experience; and the best value for your
energy dollar.

http://us4.campaign-archive2.com/?u=8e65 ldaeefld0e073215ac3 b5&id=5388805575&e=...

2/1012017

 Attachment to Response to AG-2 Question No. 9(b)
Page 44 of 170
Scott

economic Powerlines eNewsletter - Summer 2016

Online Account Management

Page 2 of3

Access your usage history in graph or table forma~.

"Our energy matters" series profiles projects that
enhance service, reliability and our environmental
commitment
Energy for today, and for the years ahead
Read more

Letting the sun shine in
New solar facility makes its debut
Rea d more

Commercial rebates offer opportunity for savings
Energy conservation leads to fina ncial reward
Read more

Natural gas flexes its muscles
Cold weather, favorable price drove increased usage
Read more

Protecting the power: clearing trees to help avoid
outages
Overgrown trees can threaten power lines
Read more

Green energy: an empowering choice
Renewable Energy Certificates help support nat ural energy providers
Read more

http://us4 .campaign~archi ve2.com/?u=8e651 daeefl d0e073 215ac3 b5&id=53 88805 57 5&e=... 2/ 10/2017

 Attachment to Response to AG-2 Question No. 9(b)
Page 45 of 170
Scott

economic Powerlines eNewsletter - Summer 2016

~ - KU_

Page 3 of3

I want to FORWARD THIS EMAIL to a friend er colleague.
Subscribe

I Urisubscribe I U. date Email I Prjyaci

Policy I Contact Us

PPt..~nles

Email sent by LG&E and KU - 220 West Main Street Louisville, KY 40202

http://us4.campaign-archive2.com/?u=8e65 ldaeefl d0e073215ac3b5&id=5388805575&e=...

2/10/2017

 Attachment to Response to AG-2 Question No. 9(b)
Page 46 of 170
Scott

major Powerlines eNewsletter- Swnmer 2016

Page 1of3

A free electronic newsletter from Mar~ White.

Trouble viewing? View Online.

0
4

.

,..

~

·~

'

LI N ES

Designed to energize businesses.

00

newsletter
Summer 2076

Take a look at our online Powerlines newsletter. We hope it provides
you with useful news and information to help you improve
your performance.
We are dedicated to excellence and ready to assist you with your
part icu lar needs. Pl ease let us know if you have any questions or
comments about this issue of Powerlines or any other issue. We
remain committed to providing you with safe, reliable service; an
exceptional customer experience; and the best value for your
energy dollar.
Mark White
Account Manager

Online Account Management

Access your usage history in graph or table format

"Our energy matters" series profiles projects that
enhance service, reliability and our environmental
commitment
Energy for today, and for the years ahead

http://us4.campaign-archi ve 1.corn/?u=8e651 daeefl d0e0732 l 5ac3b5&id=f0d23e2637 &e=3 ... 2/10/2017

 Attachment to Response to AG-2 Question No. 9(b)
Page 47 of 170
Scott

major Powerlines eNewsletter - Sununer 2016

Page 2 of3

Read more

Letting the sun shine in
New solar facility makes its debut

Read more

Natural gas flexes its muscles
Cold weather, favorable price drove increased usage
Read more

Protecting the power: clearing trees to help avoid
outages
Overgrown trees can t hreaten power lines

Read more

Shining the spotlight on our line technicians
Commitment and dedication keep the power flowing
Read more

Green energy: an empowering choice
Renewab le Energy Certificates help support natural energy providers
Read more

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I Pdvacy Policy I Contact us

Emai. sent by LG&E and KU - 220 West Main Street, Louisville, KY 40202

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 Attachment to Response to AG-2 Question No. 9(b)
Page 48 of 170
Scott

major Powerlines eNewsletter - Sunnner 2016

Page 3 of3

http ://us4 .campaign-archive l .com/?u=8 e651 daeefl d0e073 2 l 5ac3 b5&id=f0d23 e263 7&e=3... 2110/2017

 Attachment to Response to AG-2 Question No. 9(b)
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Scott

Pagel of 3

commercial Powerlines eNewsletter - Summer 2016

A free electronic newsletter for our business customers.

KU

Trouble viewing? View Online.

0

. ·: LIN ES
Designed to energize businesses.

newsletter
Summer 20 76

Take a look at our online Powerlines newsletter. We hope it provides
you with useful news and information to help you improve
your performance.
We are dedicated to excellence and ready to assist you with your
particular needs. Please let us know if yo u have any questions or
comments about this issue of Power/Ines or any other issue. We
remain committed to providing you wit h safe, reliable service; an
exceptional customer experience; and the best va lue for your
energy dollar.

Our Business Service Center is your reliable source of information and
service. Learn more about the services we ofter by visiting the Business
Service Center website.

"\
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 Attachment to Response to AG-2 Question No. 9(b)
Page 50 of 170
Scott

corrunercial Powerlines eNewsletter - Summer 2016

Page 2of3

•>

Online Account Management

Access your usage history in graph or table forma:.

"Our energy matters" series profiles projects that
enhance service, reliability and our environmental
commitment
Energy for today, and for the years ahead
Read more

Letting the sun shine in
New solar facility makes its debut
Read more

Commercial rebates offer opportunity for savings
Energy conservati on leads to financial reward
Read more

Natural gas flexes its muscles
Cold weather, favorable price drove increased usage
Read more

Protecting the power: clearing trees to help avoid
outages
Overgrown trees can threaten power lines
Read more

http://us4 .campai gn-archive2 .com/?u=8e651 daeefl d0e073 215ac3 b5&id=c£5165 fb40&e=3 .. . 2110/2017

 Attachment to Response to AG-2 Question No. 9(b)
Page 51 of 170
Scott

commercial Powerlines eNewsletter - Summer 2016

Page 3 of3

Shining the spotlight on our line technicians
Commitment and dedication keep t he power flowing

Read more

Register your account online for more power
Take a little time, get a lot of convenience

Read more

Green energy: an empowering choice
Renewable Energy Certificates help support natural energy providers

Read more

16£ "l<U.

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I Unsubscribe I Ucdate Email I prjyacy Policy I Contact Us

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by LG&E and KU - 220 w est Ma·n Street, Louisv·ue, KY 40202

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 Attachment to Response to AG-2 Question No. 9(b)
Page 52 of 170
Scott

Planting a tree?

Building a fence?
Installing a swimming pool?

Know what's

below.

Ca 11 before
Survey Mark

you dig.

ffiTl.

il()i

I Proposed hcavatlon I
Even if you're doing something as simple as
landscaping, you're required by state law to call the
One-Call Notification Center by dialing 811 before
any excavation activity.
KU will mark the location of any underground
electric lines in the area at no cost to you, so yo~'ll
know what's below and be able to dig safely.
Different colored markings
or flags indicate what lies
beneath your dig site. Wait at
least two business days before
you dig to allow time for
a PPL company
marking the lines.

Re.ck_Catd....4x9_Safe_Olgging.indd 3

319!2()16 1: 13:10 PM

 Attachment to Response to AG-2 Question No. 9(b)
Page 53 of 170
Scott

What happens when I call?
When you call the One-Call Notification Center at
811, a "locate request" goes out to member utilities,
including those who provide electric, telephone,
cable, gas and water service. Crews either mark
their underground utilities or notify you they have
no underground lines in the area. This work is
performed at no cost to you.

What if I hire a contractor?

If you hire a contractor to do excavation work,
it is the contractor's responsibility to call before
digging. Be sure to insist on this because you are
the one who will be endangered or Inconvenienced
if the contractor hits an underground utility.

For more information, visit lge-ku.com

a PPL companv

Rad<.,.Card_4ldl_Snfe_Digging.indd 4

31912016 1:13:10 PM

 Attachment to Response to AG-2 Question No. 9(b)
Page 54 of 170
Scott

I •
®

_ " ' - - L -...L......L..---L--1

•

'•

I

I

Call KU at
800-981-0600
What happens when I call?
When you call 811, a "locate request" goes out
to member utilities in your area, including those
who provide telephone, cable, gas and water
service. Some KU customers live in areas where
their underground electric service is not covered
by Kentucky 811. In those areas, call KU directly
at 800·981·0f00 and request to have your
underground electric lines marked. Crews either
mark their underground utilities or notify you they
have no underground lines in the area.

What if f hire a contractor?
If you hire a contractor to do excavation work,
it is the contractor's responsibility to call before
digging. Be sure to insist on this because you are
the one who will be endangered or inconvenienced
if the contractor hits an underground utility.

For more information, visit lge·ku.com

Racl\...Card_4x9 Sale_Ol991r19.lndd 6

31912016 1:13:10 PM

 Attachment to Response to AG-2 Question No. 9(b)
Page 55 of 170
Scott

WANT MORE POWER?
Register your account online.

KlJ
I

Rack_Card_My_Account.in(ld 3

PPL comp.1ny

312212016 11 :!50:01 AM

 Attachment to Response to AG-2 Question No. 9(b)
Page 56 of 170
Scott

REGISTER FOR 'MY ACCOUNT'
One of the easiest ways to stay 011 top of your KU account
and do business with us any time day or night is through My
Account. This safe and secure online tool - at my.lae-ku.
com - gives you 24/7 access to your account, making it
easier and more convenient for you to do all of these things.
• View your current bill
• Enroll in My Notifications - Sign up to receive convenient
bill reminders by text, email and/or voice call
• Make a payment
• Submit a request to start, stop or transfer your KU service
• Report an outage
• Sign up for energy efficiency programs
• Find out when your meter is scheduled to be read each
month
• Submit a service request to have us drop a power Une or
cover them so you can make home repairs
• View your billing and payment history
• Review and update your account information, such as your
phone number or email address
• Sign up for paperless billing (receive your bill via email)
and/or AutoPay (have your monthly payment automatically
deducted from your bank account on your payment due
date each month)
• Landlords and Property Managers: Manage your landlord
agreement(s) and make updates to your account
information
Visit my.lge-ku.com to register your account today. You
can find the information you need to register your account on
your billing statement, so you may want to have your current
bill handy when you register.
Once registered, sign in using your email address and
password wherever and whenever you want.

a PPL company

Rack_Card_My....Accoo;nl.indd 4

3122121116 11 :50:01 AM

 Attachment to Response to AG-2 Question No. 9(b)
Page 57 of 170
Scott

Report Power
Outages
From time to time, power outages
can occur in our service territory.
In most cases, power is restored in a short amount
of time. However, tornadoes, thunderstorms, ice
storms, fierce winds or extreme heat can cause more
serious outages.
When the power goes out, our personnel are well
trained and well prepared to handle such events

as quickly and safely as possible. You can help by
letting us know about outages as soon as they
occur. There are a couple of ways to do this:

Online
A quick and easy way to let us know a bout your
power outage is by signing into your account
at my.lge-ku.com. If you don't a Iready have an
online account with us, register your account today so
you're ready if the power does go out.

Why Isn't My Power Restored Yet?
Sometimes storm damage can be extensive, and repairing alt
the damage can take hours and even days. Our employees
work around the clock to make sure everyone's power is
restored as quickly as possible. Of course, we have to go about
this in a way that is safe and fairto all customers.
This Priority List will help you understand what happens
after a storm and why it may take more time to restore your
power after a major event:
The main high-voltage transmission lines which supply
energy to a large area. We must fix these lines first so
electricity can reach our substations, which in turn supply
everything else.
Emergency and life-sustaining agencies, such as
hospitals, nursing homes, tire departments and police
stations receive top priority after main transmission lines.
Critical businesses that are vital to a large number of
people, such as airports, schools and large manufacturing
facilities.
We now turn our attention to restoring the power to
the rest of our substations and tap lines. Repairing the
substations allows us to restore power to large numbers
of customers at one time, such as subdivisions. The same
with tap lines, which might affect half a dozen customers
or so. By this point, the majority of customers will
probably have their power restored.
If your power is still out but your neighbor's power is on,
you probably require individual repairs to the service
line that runs from the pole to the meter. Crews can only
make these repairs after the main transmission lines
and the substation lines have been repaired. Repairing
individual lines can take a considerable amount of time.
In some cases, you may need to hire a licensed electrician
to make repairs to your equipment before our crews can
turn your service back on.

By Phone
To report an outage or hazardous condition,
such as a downed power line, call
80~981-0600, then

PRESS 1-1 (Business customers, PRESS 2-1 ).

 Attachment to Response to AG-2 Question No. 9(b)
Page 58 of 170
Scott

Report a power outage or
hazardous condition.

POWER OUTAGE

502-589-1444
Outside Louisville

1-800-33 1-7370
Press 1-1
(Business Customers, Press 2-1)
NATURAL GAS LEAK/EMERGENCY
Press 1-1-1
(Business Customers press 2-1-1)
my.lGE-KU.com

 Attachment to Response to AG-2 Question N0. 9(b)
Page 59 of 170
Scott

 

Attachment to Response to AG-2 Question N0. 9(b)
Page 60 of 170
Scott

 

Attachment to Response to AG-2 Question N0. 9(b)
Page 61 of 170
Scott

 

Attachment to Response to AG-2 Question N0. 9(b)

FPL mules

Page 62 of 170
Scott

RELIEF SWAES
ADDEDTD EAG-IKEF

 

Attachment to Response to AG-2 Question N0. 9(b)
Page 63 of 170
Scott

 

 

Attachment to Response to AG-2 Question N0. 9(b)
Page 64 of 170

Scott
SP RAY (Pen 551595 Bug Remnant - 13 SA Made
mm
?lm m: 
Pen shape, bug repellenHJSA made. Keep the out?ow pestg away with burl,
2? pail-shapes; container ls?lled wim highly effective bug repellent liquid and

Made 01? 311% recycled material, the ace?friendly ?1352 oz. ml.) pat Rage is
US material and liquid. Makes a great give away at outdeor?u'lemed trade 5th

A?ditinnal lntormatian: Arm ynur Inga and 1.4g? you carnnaign today!

Eastman? 

WESLUCENT
GREEN

1 
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Attachment to Response to AG-2 Question N0. 9(b)
Page 65 of 170
Scott

1 95


 

Attachment to Response to AG-2 Question N0. 9(b)
Page 66 of 170
Scott

 

Attachment to Response to AG-2 Question N0. 9(b)
Page 67 of 170
Scott

 

Attachment to Response to AG-2 Question N0. 9(b)
Page 68 of 170
Scott

 

Attachment to Response to AG-2 Question No. 9(b)
Page 69 of 170
Scott

KU: SECTION 1
Payment Information

1
2
3
4

ALT TAG: Read logo as “KU bill.”
ALT TEXT: Read “3/16/16” (reads March seventh, sixteen) to read, “March seventh
two thousand sixteen.”
ALT TEXT: Read due date (reads March thirty-one, sixteen) to read, “March thirtyone two thousand sixteen.”
DOCUMENT STRUCTURE TAG: After “Due Date,” read “After due date, pay <insert
amount>.”

 Attachment to Response to AG-2 Question No. 9(b)
Page 70 of 170
Scott

KU: SECTION 2
Account Information

5
6

DOCUMENT STRUCTURE TAG: After “Service Address,” read:
ALT TEXT: “Next meter reading will occur between April second two thousand
sixteen and April seventh two thousand sixteen.”

 Attachment to Response to AG-2 Question No. 9(b)
Page 71 of 170
Scott

KU: SECTION 3
Billing Summary

7

8
9
10

11
12
13

14

ALT TAG (DOLLAR SIGN)/TEXT: Previous Balance: 137.30 (reads one hundred thirtyseven point three zero) should read as “one hundred thirty-seven dollars and thirty
cents.”
ALT TAG: Payments Received: Suppress the “S” for plural and the word “minus.”
ALT TEXT: Balance as of 3/4/16: Read as “March fourth two thousand sixteen.”
ALT TAG (DOLLAR SIGN)/TEXT: Current Electric Charges: 129.77 (reads as one
hundred twenty-nine point seven seven) should read as “one hundred twenty-nine
dollars and seventy-seven cents)
ALT TAG (DOLLAR SIGN)/TEXT: Current Taxes and Fees: 3.89 (reads as three point
eight nine) should read as “three dollars and eighty-nine cents)
ALT TEXT: Total Current Charges as of 3/4/16: Read as “Total Current Charges as of
March fourth two thousand sixteen.”
VARIABLE: If customer is on Auto Pay, read ALT TEXT: “This amount <VARIABLE –
INSERT TOTAL AMOUNT DUE> will be deducted from your bank account on
<VARIABLE – INSERT PAYMENT DUE DATE>.”
ALT TEXT: “Please contact <VARIABLE – INSERT UTILITY COMPANY NAME> by phone
at <VARIABLE – INSERT CORRESPONDING COMPANY CUSTOMER SERVICE PHONE
NUMBER> if you would like to donate to <VARIABLE – INSERT COMMUNITY
WINTERHELP for LG&E; WINTERCARE ENERGY ASSISTANCE FUND for KU;
WINTERSHARE ENERGY ASSISTANCE FUND for ODP>.

 Attachment to Response to AG-2 Question No. 9(b)
Page 72 of 170
Scott

KU: SECTION 4
Payment Information

VARIABLE: DO NOT READ THIS SECTION IF CUSTOMER IS ON AUTO-PAY
15
16
17
18
19
20
21
22

DOCUMENT STRUCTURE TAG: Online Payments: URL reads as, “L G E dash coo dot
com.” ALT TAG: “KU should read as K U.”
VARIABLE: Phone number <VARIABLE CONTENT BASED ON UTILITY AND LOCAL
VERSUS TOLL-FREE NUMBER FOR LG&E OR KU>
ALT TAG: Customer Service and Walk-In Center: “M-F” reads as “M F.” Should read
as, “Monday through Friday.”
ALT TAG: “am” reads as “am.” Should read as, “A M.”
ALT TAG: “ET” reads as “E T.” Should read as “Eastern Time.”
VARIABLE: Walk-in Customer Service Center is located at <VARIABLE CONTENT
BASED ON BUSINESS OFFICE ASSIGNMENT>
DOCUMENT STRUCTURE TAG: Mail payments to ALT TAG (Logo should read as K U)
at P O Box 9001960 Louisville Kentucky 40290 dash 1960.
ALT TEXT: “Please return stub if paying by mail. Make checks payable to <VARIABLE
– INSERT UTILITY COMPANY NAME> and write your account number on your check.”

 Attachment to Response to AG-2 Question No. 9(b)
Page 73 of 170
Scott

KU: SECTION 5
Current Electric Usage

23
24
25

ALT TAG/TEXT: Actual ( R ) Reading on 3/13/16: Suppress the “R” in parentheses;
date should read, “March fourth two thousand sixteen.”
ALT TAG/TEXT: Previous ( R ) Reading on 2/3/16: Suppress the “R” in parentheses;
date should read, “February third two thousand sixteen.”
VARIABLE: Meter Multiplier <INSERT VARIABLE NUMBER>

 Attachment to Response to AG-2 Question No. 9(b)
Page 74 of 170
Scott

KU: SECTION 6
Current Electric Charges

26
27
28

29

30

31

32

VARIABLE: Rate Type: <INSERT RATE TYPE>
ALT TAG (DOLLAR SIGN)/TEXT: Basic Service Charge reads ten point seven five.
Read as “ten dollars and seventy-five cents.”
ALT TAG/TEXT: Energy Charge: Reads “point zero seven seven four four dollars ex
one three nine seven KWH, one zero eight point one eight.” Read as “zero point zero
seven seven four four dollars TIMES one three nine seven KWH EQUALS one
hundred eight dollars and eighteen cents.”
ALT TAG/TEXT: Electric DSM: Reads “point zero zero four two three dollars ex one
three nine seven KWH, five point nine one.” Read as “zero point zero zero four two
three dollars TIMES one three nine seven KWH EQUALS five dollars and ninety one
cents.”
ALT TAG/TEXT: Fuel Adjustment: Reads “minus zero zero two zero dollars ex one
three nine seven KWH, minus zero point two eight.” Read as “minus zero point zero
zero two zero dollars TIMES one three nine seven KWH EQUALS minus twenty eight
cents.”
ALT TAG/TEXT: Environmental Surcharge: Reads “three point nine eight zero
percent ex one hundred twenty four dollars and fifty six cents, four point nine six.”
Read as “three point nine eight zero percent TIMES one hundred twenty four dollars
and fifty six cents EQUALS four dollars and ninety-six cents.”
ALT TEXT: Total Charge: Read as “Total Electric Charges.”

 Attachment to Response to AG-2 Question No. 9(b)
Page 75 of 170
Scott

KU: SECTION 7
Billing Period At-a-Glance

33
34
35
36
37
38

DOCUMENT STRUCTURE TAG: Most readers are set up to read right to left; need
DOCUMENT STRUCTURE TAG for Billing Period At-a-Glance.
ALT TAG: Read “Average Temperature This Year <NUMBER WILL READ> degrees;
last year <NUMBER WILL READ> degrees.”
ALT TAG: Read “Number of Days Billed This Year <NUMBER WILL READ>; last year
<NUMBER WILL READ>.”
ALT TAG: Read “Average Electric Charges per Day <AMOUNT WILL READ> this year;
last year <AMOUNT WILL READ>.
ALT TAG: Read “Average Electric Usage per day in kilowatt hours <AMOUNT WILL
READ> this year; last year <AMOUNT WILL READ>.
CHART: Disregard chart. Extensive programming required as screen readers are set
up to read right to left.

 Attachment to Response to AG-2 Question No. 9(b)
Page 76 of 170
Scott

KU: SECTION 8
Taxes and Fees

39

ALT TEXT: Rate Increase for School Tax: Reads as three point zero zero percent ex
one hundred twenty-nine dollars and fifty two cents, three point eight nine. Should
read as, “Three point zero zero percent TIMES one hundred twenty-nine dollars and
fifty-two cents EQUALS three dollars and eighty-nine cents.”

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Constructing LG&E and KU's Solar Share Facility
LG&E and KU plan to build, own and operate the Solar Share Facility that will be built in 500 kilowatt sections based on customer interest.
Construction will begin once a 500 kilowatt section is 100 percent subscribed. Likewise, construction on the next section and those
following will require 100 percent subscription before each section is built.
The 35-acre site; located near Conner Station Road, is large enough to accommodate a 4-megawatt (DC) solar field, which would total
about 12,000 panels.
I

What can you expect during the construction process?
• Each construction phase is expected to take between 1-4 months.
• Once construction begins, heavy equipment such as mini excavators, skid steers and telehandlers, as well as work vehicles, will be
traveling in and out of the area during the construction phases.
• An RBI hydraulic impact hammer post-driving machine will be used during normal business hours for about one week per construction
phase to install the posts used to mount the solar panels. The machine noise is estimated to reach a level of 80 decibels from about 300
feet away, which is comparable to city traffic from inside a car.
• We will take precautions to minimize road restrictions or traffic disruptions.
• Depending on weather conditions, steps will be taken to mitigate potential dust, dirt and mud
along the roadways.
1e~ i@!
•We have included plans in the project to enhance the landscaping and aesthetics to help blend
~
the facility into the beauty of the surrounding area.
~
• We will have onsite measures to deter theft and vandalism.
PPL companies

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Attachment to Response to AG-2 Question No. 9(b)
Page 77 of 170
Scott

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LG&E and KU Solar Share Facility- Simpsonville, Ky•

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Louisville Gas and Electric Company and Kentucky Utilities Company have requested permission from
the Kentucky Public Service Commission to develop a ''community" solar facility in Shelby County.
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Attachment to Response to AG-2 Question No. 9(b)
Page 78 of 170
Scott

 CONTACT US
Business Service Center

if

KU/ODP - - 85'"3,7-1200
(800·383-5582 if outside Lexington)

IMPORTANT
INFORMATION
FOR BUILDERS
AND DEVELOPERS

Representatives are available Monda~
th tough Friday from 8 a.m. until 6 p.m.

WHY DOES KU/ODP NEED A SITE PLAN?

g

bsc@lge-ku.com

lge-ku.com/ business-services

KU/ODP representatives will refer to the site plan you

Visit the builder/developer section of our website

provide when they visit the site to connect the service.

tor detailed information about the process for

Incorrect information on the site plan may result in a delay

completing your service request.

For more information, contact
your KU/ODP service locator.

in connecting service, incorrect billing to you and/or your
customers, and safety concerns with improper addressing
of electrical service.

Avoid delays. Submit a detailed site plan and
notify KU/ODP of any changes you make
along the way.

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Attachment to Response to AG-2 Question No. 9(b)
Page 79 of 170
Scott

 Whether you're a builder or developer buifding a
single-family home or developing an apartment

CONNECTING YOU

complex, office building or retail space, you are
focused on deadlines. Your project has a start date

We have exciting news! To provide an
improved Customer Experience, we have

and an anticipated completion date. Electric service

created a new central phone number
- 502-364-8744- and a dedicated email
address - new.biz@lge-ku.com - for you
to request updates, locator names and
numbers, and to submit necessary
documents. Having this centralized contact
will expedite the overall process and make
it easier to do business with us.

is critical to your project's success. A detailed and
accurate load information sheet and site plan are
extremely important to provide safe and reliable
service to both

you and your clients. Let's work

together to ensure you get the service you need,
when you need it, so you can complete your project
on time and on budget.

fj

APPLY FOR NEW SERVICE

0

CD BUILD T

(t CONNECT YOUR SERVICE

f

In any new construction project, it is important to

Once you have successfully completed the application

Before KU/ODP can connect your permanent electric

contact the KU/ODP Business Service Center {see the
back panel of this brochure tor contact information)

for service process, provided all of the required

service, the Kentucky Uniform Building Code requires

information, including a detailed load information

an electrical inspection. You (or your electrical

at the beginning of your project. The critical step of

sheet and copy of the site plan, to your KU/ ODP service

contractor or other responsible party) should contact

locator, as well as obtained all necessary permits and

the appropriate inspection authority for your area

applying for service starts the work we need to do to
ensure your customers are satisfied with their electrical
service when you hand over the keys.

easements, you can begin the construction phase of

to arrange for an inspection. After the authorized

your project.

inspection authority has approved all electrical work,
a green approval sticker will be posted at the job site.

You will be asked to provide a valid address for the
location where you need service and the date when you

Keep in mind, your service locator will be available to

would like service to start. Please provide ALL available

you througho ut construction to answer any questions

address information, such as street name, house

or address any concerns about your energy service.

energize the service can be scheduled.

KU/ODP's Business Service Center representative will
provide you with an account and/or order number,
which you should retain for future reference. You
will also be given the name and contact information
for the service locator assigned to your project. The
service locator wi II serve as your dedicated contact
for all your electrical construction needs. Please see
the "Connecting You~ information above for more

KU/ODP must be notified-by the authorized
inspection authority-before the work to

number, lot number, etc., as it is available.

We are aware that sometimes construction plans

We can only energize your service when the

change. If that occurs on your project, you must

approval sticker is in place.

contact your KU/ODP service focater when a
change affects the electric load or the site

The process for designing and installing new utility

information, or when it affects KU/ODP's service

services takes time and planning. By contacting

arrangements or ability to connect the service.

KU/ODP early in the process, working with your

information.

dedicated service locator, and providing detailed,

Your service locator will request that you provide a
detailed load informati on sheet and a copy of the site

the safe, reliab le energy and service you expect

plan for your project. KU/ODP cannot connect your
service without this important safety and planning
information.

accurate information, you can be sure to receive
and deserve.

Attachment to Response to AG-2 Question No. 9(b)
Page 80 of 170
Scott

 VISIT LG£..KU.COIVllBUDGET
TO SIGN UP TODAY.
Register or sign in to My Account at lge-ku.com/budget
or call LG&E or KU's Customer Service Department and
speak with a customer service representative. You can also
sign up at your local Business Office. Find out what your
initial Budget Payment Plan amount will be before making
the decision to sign up.

PLAN FOR MORE
PREDICTABLE
UTILITY PAYMENTS.
Join the Budget Payment Plan

CUSTOMER SERVICE

VISIT
LGE-KU.COM/BUDGET
TO SIGN UP!

Did you know you can go to My Account at lge-ku.com
and pay your bill online anytime?
You can also call 24 hours a day, 7 days a week to
learn your account balance, pay by phone or find out
when your bill is due. Use our fast path option to take
advantage of our automated system anytime, day or night.
Just call customer servic.e and press 1-2-3.

LG&E
502-589-1444

outside Louisville, call 800-331-7370

KU
800-981-0600

lge-ku.com

,,.._e

1.&3:~~

KUi,.

PPL compallies

lO£

KU~

PPL companlff

Attachment to Response to AG-2 Question No. 9(b)
Page 81 of 170
Scott

 NOW YOU CAN AVOID
SEASONAL HIGHS AND LOWS.
Very cold winters and hot, humid summers often lead to
high monthly energy use that can wreak havoc on your
monthly budget. With our Budget Payment Plan, you can
avoid seasonal peaks in your utility bills by leveling your
payments out over the course of the entire year.
This plan makes it easier for you to budget and pay
your energy bill each month.

Your initial Budget Payment Plan Amount is the average of
the previous 12 months of bills at your current address.

Find out what your Budget Payment Plan Amount will be
before you enroll. Just sign in to My Account or call to

Your account is reviewed in the fourth and the eighth
months of your Budget Payment Plan period. Any necessary
adjustments are made at those times to reduce the chance
of a large settlement amount at the end of your Budget

speak with a customer service representative. You can
also sign up at your local Business Office.

Payment Plan year in your settlement month.

{£) If you used more energy than you paid for, your

e

ftegular Monthly Payments

~

••

The white bars show the monthly
payments of someone who is
not on the Budget Payment Plan.
Payments can change drastically
from month to month as they
use more or less energy.

Budget Payment Plan
The blue line shows the monthly
payments of a customer on the
Budget Payment Plan. Their
payments remain predictable
throughout the year.

You can sign up for the Budget Payment Plan at
anytime, but we recommend signing up in lower

monthly Budget Payment Plan amount will increase.
If you used less energy than you paid for, your monthly
Budget Payment Plan amount will decrease.

LET'S LOOK AT AN EXAMPLE

WHEN IS THE BEST MONTH
OF THE YEAR TO SIGN UP?

usage months frke May, June, September or October.
This helps avoid the chance of a larger settlement
amount at the end of your Budget Payment Plan.

Review
Month

Review
Month

Settlement
Month

y

y

y

$$$$ - - - - - - - - - - - - - - - - : = - - - - . . : _ _ _ _

$$$ _

______,

$$ -1

I
$

June

July

'

Aug

Sept

Oct

Nov

Dec

Jan

Feb

March

April

May

Billing amounts represent usage from the prior month.

Attachment to Response to AG-2 Question No. 9(b)
Page 82 of 170
Scott

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Attachment to Response to AG-2 Question No. 9(b)
Page 84 of 170
Scott

  

 

Know what?s DBIOW.
Call 311 before you dig"

kentucky811.org

Attachment to Response to AG-2 Question No. 9(b)
Page 85 of 170
Scott

Feel the NEED
for 

FAST
PATH

589?1444 or 800-331-7370


 

Attachment to Response to AG-2 Question No. 9(b)
Page 86 of 170
Scott

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Attachment to Response to AG-2 Question No. 9(b)
Page 87 of 170
Scott

 CUSTOMER
COMMITMENT


   
 

Highlighting ways we focus on you.
Ige-ku.com

Attachment to Response to AG-2 Question No. 9(b)
Page 88 of 170
Scott

HOME ENERGY
REBATES
,;:.

Earn cash rebates on qualifying
energy-efficient Energy Star® appliances.
Visit lge-ku.com/rebates

Attachment to Response to AG-2 Question No. 9(b)
Page 89 of 170
Scott

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Attachment to Response to AG-2 Question No. 9(b)
Page 90 of 170
Scott

 KEEP SOMEONE SNUG

WITH A H.U.G.
\ I I

' ~"
- '"
Home Utility Gift certificates are a unique, convenient and
practical gift for anyone. Give the gift of a H.U.G. today.
lge-ku.com/hug

Attachment to Response to AG-2 Question No. 9(b)
Page 91 of 170
Scott

 COLD CASH
FOR YOUR COOLER

Fridge and Freezer Recycling Program

$50 per appliance
Visit lge-ku.com/recycle for eligibility requirements.

Attachment to Response to AG-2 Question No. 9(b)
Page 92 of 170
Scott

 STAY COOL
USING FANS

Fans use about 5o/o of the energy
it takes to power your air conditioner.
Stay cool and save using fans.
lge-ku.com

Attachment to Response to AG-2 Question No. 9(b)
Page 93 of 170
Scott

 ENERGY SAVING TIPS

-

.

~

Wash clothes in cold or warm water;
rinse in cold water. Wash full loads
or adjust water level for smaller loads.
For more energy saving tips, visit lge-ku.com

Attachment to Response to AG-2 Question No. 9(b)
Page 94 of 170
Scott

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Attachment to Response to AG-2 Question No. 9(b)
Page 96 of 170
Scott

 Enhance

Enhance

Customer Experience

Customer Experience

the

t he

Focus on and exceed customer expectations every day.
Customer Experience: Go BEYOND the obvious.

Focus on and exceed customer expectations every day.
Customer Experience: Go BEYOND the obvious.
• Who is the customer that will be impacted?

• Who Is the customer that will be impacted?
• How will this impact the customer?
•How do I want our customer to feel when the work is done?
• What can I do to make this a positive experience for the customer?
• How does my decision fit into the rest of the customer service process?

•
•
•
•

How will this impact the customer?
How do I want our customer to feel when the work is done?
What can I do to make this a positive experience for the customer?
How does my decision fit into the rest of the customer service process?

502-627-2202

502-627-2202

customer.experience@lge·ku.com
https ://teams.sp.lgeenergy.int/sites/CustExp

customer.experience@lge·ku.com
https://teams.sp.lgeenergy.int/sites/CustExp

m1CJ.

Safety First!

111£ KlJ

Safety First!

PPL c.emJtf'lfu

PPL ~Ju

+

Enhance

Enhance

Customer Experience

Customer Experience

Focus on and exceed customer expectations every day.
Customer Experience: Go BEYOND the obvious.

Focus on and exceed customer expectations every day.
Customer Experience: Go BEYOND the obvious.

t he

t he

• Who is the customer that will be impacted?
• How will this impact the customer?
• How do I want our customer to feel when the work is done?
• What can I do to make this a positive experience for the customer?
• How does my decision fit into the rest of the customer service process?

•
•
•
•
•

Who is the customer that will be impacted?
How will this Impact the customer?
How do I want our customer to feel when the work is done?
What con I do to make this a positive experience for the customer?
How does my decision fit into the rest of the customer service process?

502-627·2202

502·627-2202

customer.experience@lge-ku.com
https ://teams.sp.lgeenergy.int/sites/CustExp

customer.experience@lge·ku.com
https://teams.sp.lgeenergy.int/sites/ CustExp

Safeiy First!

m1CJ.
PPL ~m111111!0

Safety

st!

111£ IQJ.
PPLtclllt'/1fM191,N

Attachment to Response to AG-2 Question No. 9(b)
Page 97 of 170
Scott

 Be positive

KU.

Be positive

Envision yourself as the customer

Envision yourself as the customer

Yes,you make a difference

Yes, you make adifference

Own the interaction
ow is the

Own the Interaction

N

PPLcompanlu

time
Do more

111'1

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PPL camp..,,les

Be positive

Be positive

Envision yourself as the customer

Envision yourself as the customer
Yes, you make a difference
0 wn the interaction

Yes, you make adifference

UJJE KU
PPL comp&nlts

Own the fnteraction
is the time

Now
Do more

Now is the time
Domore

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IGfE KU.
PPL companl..

Now is the time
Do more

Attachment to Response to AG-2 Question No. 9(b)
Page 98 of 170
Scott

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Page 99 of 170
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Attachment to Response to AG-2 Question No. 9(b)
Page 100 of 170
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 IC

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June is National Safety Month.

Protect Yourself from

E
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a PPL c:ompany

SCAMS.

Visit lge-ku.com for important information
about scams and ways to avoid them.

fl\Akd ( ia.

@
l«I% Rc~lab.. t•por
Jt~ (.',."5-•• lt't"'v.tt'k

Attachment to Response to AG-2 Question No. 9(b)
Page 101 of 170
Scott

 IC~

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Your redesigned bill is enclosed.
DESIGNED BY CUSTOMERS
FOR CUSTOMERS

a PPL company

MONTHLY USAGE

.,,

With easy tD read information and graphs,
your new energy bill will help you better
manage your energy usage.

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Attachment to Response to AG-2 Question No. 9(b)
Page 102 of 170
Scott

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Attachment to Response to AG-2 Question No. 9(b)
Page 104 of 170
Scott

 A HOME UTILITY GIFT (HUG) IS GREAT FOR ANYONE.

it's easy, too. Just provide the name and address ofthe recipient. along with the amount you

want to give {$25 minimum}, and you'll recewe a gift certificate to present to them indicating the
amount that will be automatically deducted from their next bill.

Visit one of our business of?ces or our website at for more information,
or simply complete the HUG order form on the back.

 

Attachment to Response to AG-2 Question No. 9(b)

Page 105 of 170
Scott

Home Utility Gift (HUG) Certificate
RECIPIENT INFORMATION (Please Print)

PURCHASER INFORMATION (Pleas• Print}

Name on LG&E, KU or ODP Accoun1:

Name:~~~~~~~~~~~~~~~~~---~--~~~---~-

LG&E, KU or ODP Account No. (If known): - - - - -- - - - -- - - -

Street Address: _ _ _ _ _ __ _ __ _ __ _ _ _ _ _ _ _ _ _ __

Street Address:

City, State, ZIP;

City, State, ZIP: _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ __ _ __

Phone (required):

Name you want to appear in the "To" field of the HUG Certificate:

Name you want to appear in the "From" field of the HUG Certificate:

Amount of your HUG purchase:

IMPORTANT: Please allow 10 days for processing if you mail your HUG request form and payment.
We will credit the recipient's account und moke every effort to ensure you receive your HUG certificate
by Christmas. For orders received after Dec. 15, we will credit the recipiet>t's account; howewr, we
cannot guarantee daliwry of your HUG certlf.cate before Christmas. For HUG purchases after~. 15,
visit on e of our business offices. Check our website (lge-ku.com) or call Customer Service at the
phone number on your bal for the location and holiday hours of an office near you.

(Minimum HUG Certificate pu~nase is $25.)
Moil the completed form and your cl>eck or money order to•;

LG&E and l(U

HUG Program - Sih Floor
One Quality Street
L.exlngton, KV 40507
~Do not enclo&V this rorm \~th your

bill payment.

Attachment to Response to AG-2 Question No. 9(b)
Page 106 of 170
Scott

 Attention,
property
managers!

Attention,
property
managers!

Renew your landlord agreement online

Renew your landlord agreement online

Renew your landlord agreement onfine

Make your life easier by using lG&E and KU's Onlin•
Property Manogement Tool. especially dHlgnod kir
property managers. Jn; fast. free and use~frltndly - .u
lrours arlo11-ldlf'ISa""tlc.

Make your life easier by using LG&E and KU's Online
Property Managom&ntToot ospedally dtJlgned f<>r
propertyrnanagers. lt's his~ free and uscr/nondly-24

M•l:e your life easier by using LG&E and KU's Online
PIVp<>l'ty M•nagemenl Tool, ospecially dtsl...,ed for
prop;trty managers. ll's fast. free and u sel"frtendly- 24

hourS o rloy, 1 dors " '""'·
Here are some of' thie boisic tran5actions you can LlSe to

IHxN• o dll'f, 7 cloys o -..erk.
Her• are s<>rM of lite basic ttansactions you can use to

mmap your aaoonu.

ma~

Herw 1r1 sorn1of1f'w.ba$ic transactlons ycu can use to
manag• )O<lr aaiounts.
• S..I up and renew landlord aereements
• Update ph<>n• numbers and addrtssts
• set up and modify aut<> pay/bank dttai15
• Update existing agreements

•

~emove

aocount'S

To sign up, go to lg1t-ku.com/bs\

IDf

l<U.

PPL ~OMJf'I....

Lencl:Jid_A;!wll\tnt.lftllllf->.J1t..VERT.irdd t

OOP

• Set up and tel'll!W landlord agreements

Attention,
property
managers!

your a<counts.

• Set up ond modify auto pay/b•nk dttails
• Upd•,. exastlng agreements

•
•
•
•

• rt.rnovexcounb

• Remove accounts

• Update phcme numbers a_nd addre.ses

To sign up, go to lge-ku.com~

IDf

K'J ODP
P'L ctMNl'lfll

Set '-'P and renew landlord agrt.e:ments
Updatt phe>rae numbers and addmse:s
Set up and modify autu pay/b.>nk details
Update existing agreements

To sign up, go to lg1t-ku.com/bs-

IDf

ICJ CDP
..l"l..ioo1r1.-1tkl

~61&~~ 1

Attachment to Response to AG-2 Question No. 9(b)
Page 107 of 170
Scott

 RECOGNIZING A NATURAL GAS LEAK

~

Sight
Discolored vegetation, bubbling
in water or blowing dust.

Smell
A distinct odor. much like rotten eggs.

Sound
Hissing. whistling or roaring noise.

If you suspect a natural gas emergency, evacuate
immediately and contact LG&E. Also warn others to

"' NATURALGASSAFETY

stay away. You may call 24 hours a day, 7 days a week.

Natural gas makes our lives more comfortable and

For more information, visit us at lge-ku.com/gassafety.

effkient, and it's environmentally-friendly. We use
natural gas to heat our homes, produce hot water,
cook our meals and dry our dothes.
LG&E continuously maintains and monitors more than
4,300 miles of distribution mains and nearly 400 miles
of transmission pipelines. Your safely is important to
us; therefore, we want to make you aware of safety

~CUSTOMER SERVICE
To report an electric emergency, call LG&E or KU.
To report a natural gas issue, call LG&E. Warn others
to stay away. Call us 24 hours a day, 7 days a week.

measures related to our natural gas system in the
event you come in contact with any of our gas lines.

f

LG&E Residential

KU Residential

502·589·1444

800·981·0600

800·331-7370

ELECTRIC SAFETY

With the flick of a switch, you can heat, cool and light
your surroundings with electricity. It's so easy.
However, you must use caution when you are around
or using this energy source. Safe use of electricity can
prevent fires in your home and injuries to your family.
Here are some tips for all members <Jf your household
to follow when using electricity.

LG&E Business

KU Business

502·627·3313

859·367·1200

800·331-7370
(outside Louisville)

800·981·0600
(outside Lexington)

lge·ku.com

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PPI. companies

LG&E Gas and El0¢ti>; Safety Br<>:hure VS.fNld 1

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415116 11:08 l\M

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Attachment to Response to AG-2 Question No. 9(b)
Page 108 of 170
Scott

 "

GAS SAFETY

The smell of rotten eggs can
be a sign of a natural gas leak.

If a gas leak occurs outside your home, the grass and/or

All outdoor outlets, induding those in

any vegetation in your yard along the path of the leak

garages, should have waterproof covers

may die as a result of displaced oxygen in the soil.

and ground fault circuit interrupters (GFCI).

When using a gas range, keep
towels, potholders and clothing
away from the open flame.

If the smell is faint, check
the pilot lights on your gas
appliances. If the odor is strong

1

--

If you'll be using a ladder or pole or working
on the roof, always look up for powerlines.

Even wooden ladders can conduct
etectricity through their metal screws.

or comes on suddenly, have

Stay at least 10 feet away from overhead powerlines.

everyone leave the house.

Never use a gas oven or range to heat a room.

Do not try to find the source

The appliance will "suck" all of the
oxygen out of the air {which can lead
to asphyxiation) or may cause carbon
monoxide poisoning or death.

of the leak yourself.

Don't call for help from inside the
home since your telephone can be
an ignition source.

f

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•

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Keep flying toys, such as kites, balloons &
model airplanes, away from powerlines.

Teach children to stay away from substations
and explain what the warning signs mean.

ELECTRIC SAFETY

If a toy or pet accidentally gets inside a substation,
give us a call. We'll be happy to retrieve it for you.

Get to an area where you do not smell
~
the odor, such as a neighbor's home and
,
use their phone or a cell phone to call
LG&E at 502·589·1444 (outside Louisville,

~
1

"-

I

Cover all electrical outlets and wall
switches with cover plates and
replace any that are damaged.

Don't hang signs on utility poles. Nails, st aples or
tacks can pose a haz:ard to our workers and their
protective clothing when they climb the poles.

call 800·331-7370).

Keep paints, papers, aerosol sprays
and other flammables away from
gas appliances.

Don't yank electrical cords from the wall.
This can damage both the plug and the outlet.

Do not plant shrubs around
electric transformers or trees
under overhead electric powerlines. .,,
tr<

Don't use damaged or brittle
electrical cords, even if bare
wires aren't visible.

4'
... ,_

CaU 811 to have underground

Never store or stack boxes, laundry or other materials
around the base of a gas appliance.

utilities marked before digging.
Use extension cords only on a temporary basis;
don't plug one extension cord into another.

Make sure the vent hood, pipes and flues are
not blocked, cracked or corroded.

Stay away from and don't handle downed powerlines.

Don't run electrical cords under carpets.
This can cause them to overheat and catch fire.

Don't allow children to play on or around the gas meter

Also, avoid running cords under furniture, which can

or any gas appliance; and don't allow them to hang or

damage the insulating cover.

Just because they are down, does not mean they are
not energized. Always assume any downed
wire is an energized electric line.

swing from indoor gas pipes.

LO&E Gas and El• cv;c S.f<lly 8roctiu1e vs.;ndd 2

4/S/16 11 :08AM

I

Attachment to Response to AG-2 Question No. 9(b)
Page 109 of 170
Scott

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Attachment to Response to AG-2 Question No. 9(b)
Page 110 of 170
Scott

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n these pages, we have

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shrub varieties and classified
them - based on their height at
maturh:y - into three zones. This
information wiN prove valuable in
helping you select the right tree for the
light space.
These are only suggested varieties.
There are many other good varieties
available, but two important things to
keep in mind when deciding on tree

species are lmowing the mature height
and the mature width of the variety
before you plant

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Attachment to Response to AG-2 Question No. 9(b)
Page 111 of 170
Scott

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Attachment to Response to AG-2 Question No. 9(b)
Page 112 of 170
Scott

 APRIL 2016

COMING SOON: YOUR NEW AND IMPROVED BILL STATEMENT
JUN

JUL

AUG

SEP

OCT

NOV

CURRENT
BILLING
PERIOD

1613

1539

1635

52.7

1442

48.1

1397

Walk-in Center:

31°
31
$4.19

1359

Customer Service:

Avg. Electric Usage per Day (kWh)

ELECTRIC (kWh)

LAST YEAR

26°
29
$4.47

1246

$133.66
$133.66

Avg. Electric Charges per Day

1177

Online Payments:
Telephone Payments:

129.77
3.89

Total Current Charges as of 3/4/16
Total Amount Due

MONTHLY USAGE

THIS YEAR

Average Temperature
Number of Days Billed

1006

137.30
-137.30
$0.00

Current Electric Charges
Current Taxes and Fees

BILLING PERIOD AT-A-GLANCE

1130

Previous Balance
Payment(s) Received
Balance as of 3/4/16

Account # 0000-0000-0000

Page 2

999

BILLING SUMMARY

3/31/16
John Doe
1234 Main St
Versailles KY 40383

1336

DUE DATE

$133.66

1092

3/7/16 for Account # 0000-0000-0000

AMOUNT DUE

FEB

MAR

lge-ku.com
800-981-0600, press 1-2-3
24 hours a day; $2.25 fee

MAR

Next read will occur 4/2/16 - 4/7/16 (Meter Read Portion 02)

CURRENT USAGE

APR

MAY

DEC
2015

JAN
2016

31°

46°

58°

69°

75°

73°

76°

69°

58°

40°

38°

31°

29°

4.86

3.50

3.85

3.74

3.77

3.59

3.80

3.18

3.29

4.02

4.53

4.59

4.47

TAXES & FEES

ELECTRIC
Meter Reading Information

Rate Increase For School Tax (3.00% x $129.52)
Total Taxes and Fees

Meter # 0000000

Actual (R) Reading on 3/4/16
Previous (R) Reading on 2/3/16
Current kWh Usage
Meter Multiplier
Metered kWh Usage

65285
63888
1397
1
1397

Late Payment Charge
Late Charge to be Assessed After Due Date

$4.01

Rate Schedules
For a copy of your rate schedule, visit lge-ku.com or call our Customer Service Department.

Rate: Residential Service

Basic Service Charge
Energy Charge ($0.07744 x 1397 kWh)
Electric DSM ($0.00423 x 1397 kWh)
Fuel Adjustment (-$0.00020 x 1397 kWh)
Environmental Surcharge (3.980% x $124.56)
Home Energy Assistance Fund Charge
Total Charges

3.89
$3.89

BILLING INFORMATION

CURRENT CHARGES
ELECTRIC

10.75
108.18
5.91
-0.28
4.96
0.25
$129.77

Please return only this portion with your payment. Make checks payable to KU and write your account number on your check.

Amount Due By

3/31/16

$133.66

After Due Date, Pay This Amount:

$137.67

WinterCare Donation:

great suggestions helped us keep
everything you like and incorporate
new features to make it better.

THERE’S MORE

800-981-0600
M-F, 7am-7pm ET
Address of Business Office
City, State, Zip Code
M-F, 8am-5pm ET

AVERAGE

Mailed

Account Name:
Service Address:

Account # 0000-0000-0000
Service Address: 1234 Main St

Total Amount Enclosed:

John Doe
1234 Main St
Prospect KY 40059
PO Box 9001960
Louisville, KY 40290-1960
OFFICE USE ONLY:
MRU09831700, G000000
P200.00
PF:N eB:E

01030000000000100000000168310000001634100000000000010

KU Electric Only Statement

Designed by our customers for our customers: we’re excited to
welcome you to your new and improved utility bill, arriving next
month. The final design is the result of feedback we received from
customer focus groups and an online customer panel, whose

Your new bill will contain plenty of
Go to lge-ku.com to:
detailed information that is easy to
•  Get info on our major projects to
find and easy to understand – from
enhance safety and reliability
specific breakdowns of your energy
•  View our real-time falcon cam
usage to an easy-to-read chart
•  Find easy ways to prepare now
showing how your usage compares on
for warmer weather
a month-to-month and yearly basis.
You’ll even see your average daily
energy cost. It’s all information you can
use to become an even better energy
manager, especially when you participate in one or more of our
energy-saving programs.
We’re confident you’ll find the improvements to your KU bill to be
helpful and informative. Visit lge-ku.com/mynewbill to learn more
about the new bill design.

HERE’S TO THE TREE-PLANTING WINNERS
With April featuring both Earth Day (April 22) and Arbor Day
(April 29), it’s the perfect time for KU to announce the newest
Plant for the Planet grant recipients in our service area.
These nonprofit and local government organizations – with a
history of successful tree plantings – will each receive a
matching grant ranging from $500 to $5,000 to help fund their
tree-planting programs:
•  Shakertown at Pleasant Hill, KY, Inc. – Mercer County
•  Morehead State University – Rowan County
•  Campbellsville University – Taylor County
•  Friends of the Parks in Fayette County
•  Diamond Point Foundation and Harrodsburg Tree Board –
Mercer County

•  Henderson County Parks and
Programs
Not only are trees a beautiful part of the
landscape and vital to the ecosystem,
they also play an important role in
conserving energy. In the summer, trees
provide shade. In the winter, they help
provide warmth and protection from the
cold winter wind.
Applications for next year’s Plant for the
Planet grants will be accepted beginning
in November. Mark your calendar now.
Visit lge-ku.com/plantfortheplanet to
learn more about the program.

•  The Arboretum, State Botanical Garden of KY –
Fayette County

PICK UP THE PHONE BEFORE GRABBING THE SHOVEL
Spring has sprung, and you
can’t wait to get out in the yard
to start planting … flowers,
shrubs, trees. Or maybe you’re
going for a bigger project, such
as building a deck. But wait.
Before you dust off that shovel,
you need to make a phone call
to have your underground
utility lines marked so you know where it’s safe to dig. (It’s the
law.) Visit our website at lge-ku.com to see if you need to call KU

directly or if you can simply call 811. Once you call 811, member
companies, including KU, will mark their underground wires or
pipelines on your property whether it’s electric, cable or water.
That gives you peace of mind. You’ll know what areas to avoid,
and you can save yourself a costly repair or even a serious injury.
So, plan ahead and make the call (at least two business days
before you plan on digging). The service is free, and that shovel’s
not going anywhere.

Sign up for My Notifications and receive timely reminders about the due date of your bill by text, email and/or phone.
Visit my.lge-ku.com for more information.

Attachment to Response to AG-2 Question No. 9(b)
Page 113 of 170
Scott

 PROTECTING THE POWER: CLEARING TREES TO HELP AVOID OUTAGES
Providing safe,
reliable energy at
some of the lowest
costs in the nation
is what KU is all
about. One of the
things that is most
critical to reliability
is making sure trees
are properly
trimmed so they
don’t threaten power lines. Sometimes trees are planted near
power lines. Over time, if not maintained, tree growth can cause
hazards. Our Power Line Tree Clearance program keeps

overhead power lines clear of limbs and brush, allowing our
crews to detect and repair issues that impact service during
storms or other events.
We use only experienced professionals to clear trees, and all
work is supervised by our certified arborists. Crews are careful to
use proper trimming methods to protect healthy trees. What you
will see most often are “V” or “L” cuts, which are the best
techniques to maintain tree health and also provide the best
chance to keep trees from growing back into the power lines
before the next scheduled clearing cycle.
Visit lge-ku.com to learn more about how we work to protect
both power lines and trees.

WE’RE BIG FANS OF FANS
When using a ceiling fan to help stay cool, be
sure the blades are set to move
counterclockwise to draw cooler air upward.
And remember during cool or colder weather,
setting the fan in a clockwise direction helps
push warm air down.

Believe it or not, it won’t be long before it’s
time to start thinking about keeping cool
and flipping on the air conditioner.
When that time comes, it’s good to
remember that fans, particularly ceiling
fans, can help cool you and save you quite
a bit of energy. For example, a single
ceiling fan takes only about five percent as
much energy as is needed to power your
air conditioner. That allows you to set your
thermostat a little higher and reduce the
amount of time your air conditioner
is running.

Look for the Energy Star® label when buying a
ceiling fan for even more energy savings.
Energy Star models use half as much
electricity as standard units. Visit lge-ku.com
for more energy-saving tips.

WANT MORE POWER? REGISTER YOUR ACCOUNT ONLINE
One of the easiest ways to stay on top of your KU account and do
business with us is through My Account. The safe and secure
online tool gives you 24/7 access to your account, making it easier
and more convenient for you to:
•  View your current bill and billing history.
•  Enroll in My Notifications – convenient bill reminders by text,
email and/or voice call.

•  Submit a service request to
have us drop your power
lines or cover them so you
can make home repairs.
It takes just a few minutes to
register. Visit my.lge-ku.com to
sign up today.

•  Make a payment or view your payment history.
•  Report an outage.
•  Sign up for our energy-efficiency programs, paperless billing
and AutoPay.

KU
Contact
Information

By Phone
Monday–Friday
7 a.m.–7 p.m. (Eastern Time)
Self-Service by touch-tone phone
or web:
Anytime day or night
For Hearing- or Speech-Impaired
Dial 711

Business Service Center
 
Monday–Friday
8 a.m.–6 p.m. (Eastern Time)

Editor
Visit our website:
lge-ku.com

In-Person
Customer Service Walk-in Centers
Monday–Friday
9 a.m.–5 p.m. (Eastern Time)
Lexington Office: 8 a.m.–5 p.m. (ET)

Like us on Facebook (facebook.com/lgeku) and follow us on Twitter (@lgeku) and Instagram (lge_ku).

Attachment to Response to AG-2 Question No. 9(b)
Page 114 of 170
Scott

 AUGUST 2016

SAFE, LOW-COST POWER FOR TODAY,

THERE’S MORE

TOMORROW AND BEYOND

Go to lge-ku.com to:

The solar facility at the E.W. Brown plant and the natural gas
combined-cycle unit at Cane Run are a couple of the major
investments you’ve read and heard about which demonstrate
our constant and continuing commitment to meeting the energy
demands of the future in a safe, reliable and cost-efficient
manner. While those projects have received a lot of attention,
there are other – but no less important – investments being
made to help us make sure we keep that promise.
For example, we are purchasing a new portable transformer
to improve the ability to maintain service during planned or
unplanned substation transformer outages. And we continue to
explore new technologies to reduce the frequency and duration
of outages throughout our service area.

So, whether it’s making sure there are
backup parts on hand to meet any
situation or a project to improve
environmental quality, KU will keep
making investments to ensure we
continue to provide you with the safe,
reliable energy you deserve.

•  See how we’re planning to meet
your future energy needs
•  Find out how clearing trees
improves reliability
•  Learn about co-op/internship
opportunities for
college students

Visit lge-ku.com/investments to learn
more about some of the investments we’re making and the
people behind them.

TIME FOR A LESSON ON SOME ABCS OF ENERGY EFFICIENCY
When it comes to energy efficiency, we’re all
students in a way. Learning ways to save energy
helps us become better stewards of the
environment as well as smarter users of
our money. So, with school days nearing
(or already under way in some cases),
maybe a few ABCs of energy efficiency
will come in handy, whether you’re a
homeowner looking for some helpful tips or a teacher working
on a classroom topic:

•  B – Buy better bulbs. LED lights and CFL bulbs last
longer and are much more energy efficient than older
incandescent bulbs.
•  C – Compare the cost. When buying a new appliance, there
are two costs to consider: 1) the cost of the appliance itself
and 2) the cost of the energy to run it. An ENERGY STAR®
certified model will use less energy and save you money
in the long run.
No homework tonight, but there may be a quiz later.
Class dismissed.

•  A – Add additional insulation. Plugging up those drafty
areas around doors and windows will help keep cool air
from escaping during the warm months and stop cold
air from entering during the winter.

SPEND A LITTLE MORE NOW, SAVE A LOT MORE LATER
As with most things, sooner or later, you’ll have
to replace your old appliances. When you get to
that point – whether it’s a new refrigerator, a new
stove, a new dishwasher, etc. – there’s a key piece
of information you’ll want to consider before
making a purchase: the ENERGY STAR®
EnergyGuide label. It gives you an estimate
of how much energy the appliance will use
each year and how much the energy will cost.
There can be wide variances, so it pays to factor
the energy cost in along with the price tag on the
appliance. The more energy efficient the
appliance, the more you save over time.

U.S. Government

Federal law prohibits removal of this label before consumer purchase.

Refrigerator-Freezer
Automatic Defrost
Bottom-Mounted Freezer
Without Through-the-Door Ice

Model(s): GDSCOKBX GDSSOKCX
GDSCOKCX GDSSOKBX
GDSLOKCX
Capacity: 20.2 Cubic Feet

Energy consumption
/ Consommation
énergétique
You
can also
get cash
back from KU when you buy a
more energy-efficient appliance. The Home Energy
kWh helps
Rebates program
per year / par
année defray some of the cost of
higher-efficiency products by offering cash rewards.
Learn about the program by visiting lge-ku.com and
Type 5
clicking on18.5the
- 20.4 Saving Energy & Money tab.

455

Estimated Yearly Operating Cost
B
0

$48
$47

So, just going with the lowest purchase price may not
be the smartest move; you can pay less now but end
up paying more in the long run.

This model/ Ce modèle

Cost Range of Similar Models

$61

B
2

455

kWh

Estimated Yearly Electricity Use

Your cost will depend on your utility rates and use.
Cost range based only on models of similar capacity with automatic defrost,
bottom-mounted freezer, and without through-the-door ice.
Estimated operating cost based on a 2007 national average electricity cost
of 10.65 cents per kWh.
For more information, visit www.ftc.gov/appliances.
225D2359P018A

435 kWh

569 kWh

Uses most energy /
Consomme le plus
d’énergie

Uses least energy /
Consomme le moins
d’énergie

Similar models
compared
Model number

volume in ft3 / volume en pi 3

GDSCOKBX
GDSSOKCX

GDSCOKCX
GDSSOKBX

GDSLOKCX

Modèles similaires
comparés

Numéro du modèle

REMOVAL OF THIS LABEL BEFORE FIRST RETAIL PURCHASE IS AN OFFENCE (S.C. 1992, C. 36).
Enlever cette étiquette avant le premier achat au détail constitue une infraction (L.C. 1992, ch. 36).
The ENERGY STAR ® mark on this EnerGuide label signifies that this
in an energy-efficient appliance. Its energy performance meets or
exceeds the Government of Canada’s high efficiency levels. Use the
EnerGuide rating to determine how this appliance compares to other
similar models.
La marque ENERGY STAR ® sur cette étiquette ÉnerGuide signifie
que l’appareil est éconergétique et que son rendement énergétique
satisfait ou dépasse les niveaux d’haute efficacité du gouvernement
du Canada. Utilisez la cote ÉnerGuide afin de comparer le rendement
de l’appareil avec celui d’autres modeles similaires.
225D2359P018 B

Sign up for My Notifications and receive timely reminders about the due date of your bill by text, email and/or phone.
Visit my.lge-ku.com for more information.

Attachment to Response to AG-2 Question No. 9(b)
Page 115 of 170
Scott

 WE HOPE YOU’RE DIGGING THIS INFORMATION ABOUT DIGGING
No one likes to get hurt. And no one likes to
lose any of their utility services.
Those are two good reasons to practice safe
digging. That means calling 811 before
you start to dig any hole for any reason.
Failure to call means you’re breaking the law
and subjecting yourself to significant fines.
And you run the risk of damaging
underground lines or pipes, seriously injuring
yourself or causing a service interruption.
Is that bush or mailbox really worth it?
Probably not.

A quick call to 811 (dial 8-1-1) or visit to the 811 website at
811now.com to submit your request online notifies member
utilities to mark any underground lines or pipes on your property.
It’ll be done within a few days, and it doesn’t cost you a thing.
So, make safety a top priority by planning ahead and making your
request online or on the phone.
If you live in an area where your KU service is not covered
by Kentucky 811, call
to request to have KU mark
your underground electric service. Visit lge-ku.com to find
out if you need to contact KU or 811.

KEEPING LANDLORDS PLUGGED IN TO THE DETAILS OF UTILITY BILLING
Keeping track of utility billing can be a bit of a challenge if you
are a landlord. KU’s Landlord Agreement helps make that job
easier. The agreement ensures utility services remain active at
rental locations.
Per the agreement, when a tenant requests to have electric
service discontinued, future service will be transferred and
billed to the account and name listed on the Landlord
Agreement, until a new tenant applies for service.
If service to a tenant is cut off due to nonpayment, the service
will remain off until the delinquent balance is paid in full by

the tenant or the tenant vacates the property and the
landlord authorizes the service to be transferred back
into his or her name.
The landlord agrees to notify KU when a tenant vacates the
property and to let the company know if a listed property is sold
so it can be removed from the agreement.
Finally, the landlord is responsible for payment of any bill that is
issued for electric service provided at the rental property until
the company is notified of any changes to the account.

AN EASY WAY TO REPORT A POWER OUTAGE IS RIGHT
AT YOUR FINGERTIPS
If you lose power during a storm or as the result of some other
emergency situation, send us a text to report the outage. It’s as
easy as 1-2-3:
1. Add your cellphone number to your KU account. Sign in to
your online account and enter your number. If you do not have
an online account, visit my.lge-ku.com to easily create one.
2. Add LG&E-KU to your contacts. Use 4LGEKU (454358)
for the number.

To get updates about the
power outage in your area, text
the word STATUS to the same
contact number.
Also, remember you can visit
lge-ku.com to check out the
Storm & Outage Map for
additional information.

3. If the power goes out, simply text OUTAGE to the
contact number.

KU
Contact
Information

By Phone
0
Monday–Friday
7 a.m.–7 p.m. (Eastern Time)
Self-Service by touch-tone phone
or web:
Anytime day or night
For Hearing- or Speech-Impaired
Dial 711

Business Service Center
 
Monday–Friday
8 a.m.–6 p.m. (Eastern Time)

Editor
Visit our website:
lge-ku.com

In-Person
Customer Service Walk-in Centers
Monday–Friday
9 a.m.–5 p.m. (Eastern Time)
Lexington Office: 8 a.m.–5 p.m. (ET)

Like us on Facebook (facebook.com/lgeku) and follow us on Twitter (@lgeku) and Instagram (lge_ku).

Attachment to Response to AG-2 Question No. 9(b)
Page 116 of 170
Scott

 FEBRUARY 2016

PLEASE NOTE: WE’RE ADJUSTING SOME SERVICE HOURS
Self-service options, such as our website and
automated phone system, have become
increasingly popular. With that trend in mind, we
have adjusted the operating hours for our
Business Service Center and the majority of our
customer service walk-in centers.
Business Service Center (by Phone)
Our Business Service Center representatives
are available by phone from 8 a.m. to
6 p.m. Eastern time Monday–Friday.

service walk-in centers (not including
Lexington) will open at 9 a.m. Eastern
time Monday–Friday.
Providing the best customer service
possible is always a top priority for us at
KU. From our mobile-friendly website and
speed-dial tools, to outage texting and
My Notifications, we’re focused on
making sure you get fast and easy access
to the information you need and want.

THERE’S MORE
Go to lge-ku.com to:
•  Learn about our commitment
to protect the environment
•  Find energy-saving tips
•  Read storm/outage information

To learn more about KU’s customer service offerings, visit our website
at lge-ku.com.

Customer Service In Person
Effective March 14, our customer

MAJOR INVESTMENT PLANNED TO MEET ENVIRONMENTAL REQUIREMENTS
KU plans to invest $678 million in environmental projects over the
next several years to meet required Environmental Protection
Agency regulations, including the Coal Combustion Residuals (CCR)
rule, which became effective last year. The funds will go mainly to
cap and close the utility’s remaining ash ponds at the E.W. Brown
and Ghent generating stations as well as the now-retired Green
River, Pineville and Tyrone coal-fired power plants – placing a secure
cover, or cap, over the ponds as a precursor to full closure. Other
projects include additional mercury control systems, construction of
process-water facilities and the second phase of the Brown landfill.
The CCR rule established new requirements for the disposal of the
byproducts left over after coal is safely burned to make electricity. It
also established new standards expected to require – over the next
three years – commencing or completing closure of ash ponds and

some other on-site wet storage sites. KU expects to begin these
latest investments in the environmental improvements in 2016 and
continue through 2023.
The $678 million plan represents the lowest reasonable cost for KU
to meet the latest environmental requirements while continuing to
beneficially use byproducts in a safe and practical manner. The utility
has filed a request with the Kentucky Public Service Commission to
recover the costs for the projects.
The EPA determined that coal combustion residuals are
nonhazardous materials and can continue to be beneficially used
to make certain authorized products and for specific uses.
Byproducts produced at KU plants have been reused off-site to
create products such as concrete, wallboard and fertilizers.

CONSTRUCTION UNDERWAY ON SOLAR FACILITY
Construction is underway on the much-anticipated solar facility
at the E.W. Brown Generating Station in Mercer County, Ky. It is
expected to be up and running by late spring of 2016. The new
10-megawatt facility, approved by the Kentucky Public Service
Commission in December of 2014, will sit on approximately 50
acres of the plant’s property and consist of more than 45,000 solar
panels on a fixed-tilt rack system. The panels will be positioned to
optimize available sunlight for producing energy. The site is
projected to produce its full potential approximately 400 hours
annually (4.5 percent of the year). The panels are projected to
produce 19,000 megawatt hours of energy, enough to provide
energy to 1,500 homes based on an average usage of 1,000
kilowatt hours per month.
Thanks to competitive bidding, the final cost to build the facility is
expected to be less than the original $36 million estimate.
Artist rendering of E.W. Brown solar power facility

Sign up for My Notifications and receive timely reminders about the due date of your bill by text, email and/or phone.
Visit my.lge-ku.com for more information.

Attachment to Response to AG-2 Question No. 9(b)
Page 117 of 170
Scott

 HERE’S ANOTHER TYPE OF POWER TO HELP YOU MANAGE YOUR LIFE
You already have enough to
remember: a trip to the grocery to
grab something for dinner, a doctor’s
appointment, a birthday party, an
appointment with the cable guy, and
on and on. You don’t need the added
stress of remembering to pay your
utility bill. All you need is My
Notifications. Sign up for KU payment
reminders and you can choose to be
notified by text, email, phone call or
a combination of all three. You can
even tell us when you want to be

notified – as soon as your bill is available, five days before it’s
due or one day past its due date.
And to make managing your monthly bill even easier, sign up
for paperless billing. It’s very easy to do – and once you’re
signed up, we’ll send you a safe and secure email each month
letting you know your bill is available for viewing when you sign
in to your online account.
Get signed up for My Notifications and paperless billing today
at my.lge-ku.com.

PAY CLOSE ATTENTION TO WHERE AND HOW YOU STORE FLAMMABLE LIQUIDS
Let’s be clear: the proper storage of flammable liquids is vital to
you and your family’s safety. Failure to heed the proper
precautions when storing gas, paint thinner, solvents and other
potentially dangerous liquids could result in serious injury or even
death. These liquids can ignite and burn easily, so be sure to
follow these guidelines to avoid any tragedy:
•  Keep ’em outside – unless absolutely necessary, store
flammable liquids outside rather than inside your home.
•  Use correct containers – only approved safety cans should be
used, and all containers and cabinets should be properly
labeled with the appropriate flammable liquids signs.

•  Keep burners and pilot lights elevated –
appliances that are near stored flammable
liquids must have their main burners and
pilot lights elevated by at least 18 inches.
Vapors from flammable liquids can
travel along the floor and be
ignited if those ignition sources
are at floor level.
•  Keep ‘em away from the kids – make
sure flammable liquids are not where
children can reach them.

CHANGING “FILL ’ER UP” TO “CHARGE ’ER UP”
Charging stations for electric
vehicles might become more
common sooner than you think.
As an energy partner, KU would
like to work with business
customers by installing and
maintaining EV charging
stations for them. To start
the process, we filed an
application with the Kentucky
Public Service Commission
in November.

Since 2010, there have been nearly 700 plug-in capable electric
vehicles registered in Kentucky, according to the Electric Power
Research Institute. While that’s a small percentage of the total
number of registered vehicles in the commonwealth, the number
is on the rise.
Under the proposal, business customers can choose to host
charging stations. Business customers would pay a monthly fee,
be asked to commit to a five-year term and be responsible for
installation costs. The company would operate and maintain the
charging stations. Learn more at lge-ku.com.

The request seeks approval for
20 charging stations in
public-access areas such as
parking lots, street parking
and other outdoor areas.

KU
Contact
Information

By Phone
Monday–Friday
7 a.m.–7 p.m. (Eastern Time)
Self-Service by touch-tone phone
or web:
Anytime day or night
For Hearing- or Speech-Impaired
Dial 711

Business Service Center
 
Monday–Friday
8 a.m.–6 p.m. (Eastern Time)

Editor
Visit our website:
lge-ku.com

In-Person
Customer Service Walk-in Centers
Monday–Friday
9 a.m.–5 p.m. (Eastern Time)
Lexington Office: 8 a.m.–5 p.m. (ET)

Like us on Facebook (facebook.com/lgeku) and follow us on Twitter (@lgeku).

Attachment to Response to AG-2 Question No. 9(b)
Page 118 of 170
Scott

 MARCH 2016

THUNDER, LIGHTNING, WIND AND RAIN: BE READY
The coming of spring means an increased
likelihood of severe storms and
tornadoes. March is Severe Weather
Preparedness Month, so now is a good
time to prepare an emergency kit to
keep on hand if a storm leaves you in
the dark for an extended period of time.
Some things you’ll need include:
•  Nonperishable food

Also, don’t forget to take these
steps to be prepared if a storm is in
the forecast:
•  Keep your cellphone charged.
•  Fill your car’s gas tank.
•  Turn off all appliances (but leave
a light switch on so you’ll know
when power is restored).

THERE’S MORE
Go to lge-ku.com to:
•  Learn more ways to save
energy and money
•  Read about the importance
of calling before you dig
•  Find out how to get billing
notification by text, email
or phone

Never go near a fallen wire or power
line. Always assume it’s live and call us right away
at
.

•  Water
•  A battery-operated radio
•  Flashlights

Visit our website at lge-ku.com to see our outage map, report a
problem and get more storm preparation tips.

•  Extra batteries
•  First-aid kit (including
prescription medications)

TEXT US TO TELL US WHEN THE POWER GOES OUT
Now you’re ready to report a power
outage. Simply text OUTAGE to 4LGEKU
(454358) and text STATUS for updates.
Don’t forget you can also visit our website
at lge-ku.com to see our outage map,
which provides information about outages
in our service area by county and ZIP code.

The inevitable spring storms mean potential
downed power lines and loss of power. One of the
easiest ways to let us know your electricity is out is
right in your hand – just use your cellphone to
send us a text. Set your phone up today for outage
texting. It’s fast and simple:
•  Sign in to your online account and enter your
current mobile number under My Profile/
Contact Information. If you do not have an
online account, create one at my.lge-ku.com.
•  Once your mobile number is entered, add us
to your contacts using the number 454358.

WE’RE NOT JUST BLOWING HOT AIR: CLEAN YOUR DRYER
FILTER FOR ENERGY SAVINGS
Don’t laugh. If lint builds up on the lint filter in your dryer
between loads, the machine is forced to work a little bit harder
to do its job, increasing energy usage and cost. The simple
solution is to remember to clean the filter after each load to
improve air circulation.
Here are some other tips for making sure you get the most
energy efficiency out of your dryer:
•  Give the dryer a vacation – hang clothes outside to air-dry
when the weather allows or inside when it doesn’t.

•  Don’t ask too much of the dryer
– don’t try to dry too many
items in a single load. In other
words, don’t overload it.
•  Don’t ask too little of the dryer
– dry full loads whenever
possible. The same amount of
energy is used for full loads as
for loads of just a few items.

•  Once you get started, keep going – dry several loads back
to back.

Sign up for My Notifications and receive timely reminders about the due date of your bill by text, email and/or phone.
Visit my.lge-ku.com for more information.

Attachment to Response to AG-2 Question No. 9(b)
Page 119 of 170
Scott

 KEEP THE OUTSIDE AIR IN ITS PLACE
Simply put, air leakage means unwanted outside air entering
your home through cracks or openings. And that can cause cash
leakage in the form of higher utility bills. So, finding those leaks
and plugging them up is good for your comfort as well as your
bank account.
If you haven’t done so in a while, now is a good time to look
for places where air may be entering your home. Windows and
doors often take a pretty good beating during the worst of
winter. A good place to begin your inspection is the caulking
around your doors and windows. It should be soft, without
cracks. To test for leaks, try lighting a candle and holding it
next to the doors and windows. Smoke drifting is a sign air is
intruding from the outside.

There are several ways to seal leaks, from caulk and spray foam
to weather stripping and door sweeps. A little time and elbow
grease can help ensure that you “air” on the side of savings
and comfort.

DON’T LET WARM AIR GO UP, UP AND AWAY
While we’re on the subject of air
leakage, you may be aware of what
is called the chimney effect, which
basically derives from the principle
that warm air rises. During cold and
cool weather, air can escape by
various means – attic vents, recessed
lights, ceiling fans – whether or not
your house has a chimney.
Again, where practical, seal the
potential escape routes. You can

also mitigate the chimney effect by keeping the damper
closed on your chimney when you are not burning a fire and
by closing vents.
And don’t forget the basement. The space along the top of
the basement wall – where the cement or blocks come into
contact with the wood frame of your home – is a common area
for air to escape.

YOUR PATH TO INFORMATION – THE FAST PATH, THAT IS
At KU, we’re all about making sure you have quick and easy
access to the information you need, when you need it and how
you want it – 24 hours a day, seven days a week. Speed Dial
provides a fast-path option that allows you to obtain account
information – such as the amount due and your payment due
date – and quickly make a payment by phone if you want to do
so. Just give us a call at 800-981-0600 and then enter a few
numbers per the menu below to get the service you want when
you want it.
Speed Dial

•  1-2-3 – make a payment by phone
•  1-2-4 – find payment options, discover locations where you
can pay your bill or request a copy of your current bill
•  1-1-2 – report a power outage or other hazardous condition
If you prefer to speak to a person, enter 1-3 to be connected to
the next available representative. Representatives are available
Monday–Friday from 7 a.m.–7 p.m. Business customers should
enter 2-3 to speak to a representative. Business Service Center
specialists are available Monday–Friday from 8 a.m.–6 p.m.

•  1-2-1 – learn account balance or payment due date
•  1-2-2 – make payment arrangements
KU
Contact
Information

By Phone
Monday–Friday
7 a.m.–7 p.m. (Eastern Time)
Self-Service by touch-tone phone
or web:
Anytime day or night
For Hearing- or Speech-Impaired
Dial 711

Business Service Center
 
Monday–Friday
8 a.m.–6 p.m. (Eastern Time)

Editor
Visit our website:
lge-ku.com

In-Person
Customer Service Walk-in Centers
Monday–Friday
9 a.m.–5 p.m. (Eastern Time)
Lexington Office: 8 a.m.–5 p.m. (ET)

Like us on Facebook (facebook.com/lgeku) and follow us on Twitter (@lgeku).

Attachment to Response to AG-2 Question No. 9(b)
Page 120 of 170
Scott

 SEPTEMBER 2016

SUNNY DAY: TAKING A BIG STEP TOWARD CREATING
A COMMUNITY SOLAR FACILITY
Last month, KU and its sister utility, Louisville Gas and Electric
Company, filed a request with the Kentucky Public Service
Commission to develop a “community” solar facility in Shelby
County, Ky. The subscription-based Solar Share Program
proposes constructing a regional facility for the utilities’
residential, business and industrial customers interested in sharing
local solar energy and receiving solar energy credits generated
from the facility.
The 35-acre site, along Interstate 64 in the KU service territory,
is large enough to accommodate a 4-megawatt solar field.
However, Solar Share will be built in 500-kilowatt sections based
on customer interest. Construction will begin once a 500-kilowatt
section is 100 percent subscribed. Likewise, construction on the
next section and those following will require 100 percent

subscription before each section
is built.

THERE’S MORE
Go to lge-ku.com to:
•  Learn about our environmental
upgrades and how we’re
planning for the future

Interested customers can visit
•  Find simple energy-saving tips
lge-ku.com/solar to learn more about
•  Meet some of our employees
Solar Share and fill out an online
who help keep the lights on
interest form to request updates when
available. Those completing the form
are under no obligation to participate
in the program. Once the regulatory process is complete,
customers will decide if they would like to complete the
enrollment process with the utilities and pay their nonrefundable
subscription fee.

CLEANER SKIES AHEAD: $2.8 BILLION IN

ENVIRONMENTAL PROJECTS CUTTING AIR EMISSIONS
The program included constructing additional environmental
controls at the company’s E.W. Brown, Ghent, Mill Creek and
Trimble County power plants to further reduce sulfur dioxide
and nitrogen oxide emissions, as well as installing technology to
capture mercury and fine particulates. For example, we installed
10 baghouses across the generating fleet. These massive
structures cost more than $100 million each and contain 17,280
bags – each about 27 feet long – acting like giant vacuum
cleaners that trap fine particulates and mercury.
These projects met all performance guarantees while coming in
well-below the original $3.1 billion estimate, producing
significant savings for our customers.
“The success of these projects is attributed to our employees
and contract partners,” said Scott Straight, director of Project
Engineering for LG&E and KU. “It’s a significant feat and huge
milestone for the companies to complete construction projects
of this magnitude safely, under budget and on time.”

KU’s commitment to providing our customers with efficient,
low-cost energy that is environmentally friendly and complies
with federal clean air regulations has never been stronger.
In 2011, the company (and its sister utility LG&E) received
approval from the Kentucky Public Service Commission for its
comprehensive environmental plans to meet the new and more
stringent air quality regulations. This multibillion-dollar plan,
the largest construction program in the company’s history, is
nearing completion.

The company’s compliance plan also resulted in the retirement
of six coal-fired power plants, replacing them with a highly
efficient, state-of-the-art natural-gas-fired combined cycle plant
– the first one in Kentucky – at LG&E’s Cane Run site in Louisville.
In addition to significant reductions in sulfur dioxide, nitrogen
oxide and fine particulates, the new Cane Run plant decreases
carbon dioxide emissions and saved our customers millions of
dollars in fuel costs.
Visit lge-ku.com/investments to learn more about these
projects, the company’s ongoing investments and the people
behind them.

Sign up for My Notifications and receive timely reminders about the due date of your bill by text, email and/or phone.
Visit my.lge-ku.com for more information.

Attachment to Response to AG-2 Question No. 9(b)
Page 121 of 170
Scott

 BASKING IN THE BREEZE KEEPS CASH FROM BLOWING AWAY
Fans are great for
helping your energy
dollar go a bit further.
For example, a breeze
from a fan helps keep
you cool during
warmer weather, which
means you can save
energy by raising your
thermostat a degree or
two. Plus, you realize additional savings by reducing wear and
tear on your air-conditioning unit. Just remember that fans cool
bodies, not rooms, so turn them off when you leave the room.
And just because we’re heading into fall doesn’t mean you can’t
benefit from using fans. If you have ceiling fans, run the fan on low
speed and flip the switch when the weather gets cooler so the

blades move clockwise. That pushes air upward, where hot air
normally is, and dispenses it more evenly throughout the room.
In some two-story homes, this helps warm the air on the lower
level – where the thermostat usually is.
Finally, choosing the right fan can make a difference.
When shopping for a ceiling fan, get an ENERGY STAR® certified
model because they use half the energy of a standard unit.
By using these American Lighting Association guidelines, you can
get the right size fan for the room:
•  Up to 75 sq. ft. – 29"–36"
•  76 sq. ft. to 144 sq. ft. – 36"–42"
•  145 sq. ft. to 225 sq. ft. – 44"
•  226 sq. ft. to 400 sq. ft. – 50"–54"

ONE MAY BE THE LONELIEST NUMBER, BUT IT’S ALSO THE EASIEST
date of withdrawal. You may also want to consider
enrolling in My Notifications to receive timely
reminders about the due date of your bill by text,
email and/or phone.

Whether you own a home or a business, we want
to make sure doing business with us is easy.
One option we offer business owners – also known
as commercial customers – who have several
meters and facilities, and therefore multiple bills,
is our Collective Billing feature. Simply put, all the
charges for every account you have with us are
included in one bill, rather than several individual
bills. This means that only one check – not multiple
ones – needs to be written for payment. Or you
could skip the check altogether by signing up for
Auto Pay. That way your single payment is
automatically deducted from your bank account.
You still receive a statement in plenty of time to
verify the information and record the amount and

Although there is only one bill, each separate
account and its balance is shown on a detail-listing
page, so that information is always available.
Collective Billing is free and easy. Visit lge-ku.com
or call
to find out how to sign up.
With Collective Billing, commercial customers save
paper, reduce the time and expense of processing
checks, reduce postage costs and improve
operating efficiency.

FOR COLUMBUS DAY, WE’RE SAILING ON A SEA OF SERVICE
KU’s Customer Service offices and call centers will be closed on
Columbus Day (Monday, Oct. 10) in observance of the federal
holiday. Customer Service employees will spend the day in
training to discover new ways to serve you.

Remember, your bill is never due on a day the offices are closed.
You can still make a payment by phone on that day if you like by
calling
and then pressing 1-2-3. Payment can also
be made at one of our authorized pay agents or by using your
online account. Visit our website at lge-ku.com to find the
location of an authorized agent near you, to sign in to or register
your online account and to see all the available options for
paying your bill.

KU
Contact
Information

By Phone
Monday–Friday
7 a.m.–7 p.m. (Eastern Time)
Self-Service by touch-tone phone
or web:
Anytime day or night
For Hearing- or Speech-Impaired
Dial 711

Business Service Center
 
Monday–Friday
8 a.m.–6 p.m. (Eastern Time)

Editor
Visit our website:
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In-Person
Customer Service Walk-in Centers
Monday–Friday
9 a.m.–5 p.m. (Eastern Time)
Lexington Office: 8 a.m.–5 p.m. (ET)

Like us on Facebook (facebook.com/lgeku) and follow us on Twitter (@lgeku) and Instagram (lge_ku).

Attachment to Response to AG-2 Question No. 9(b)
Page 122 of 170
Scott

 Mailed 4/29/16 for Account #

1
BILLING SUMMARY
Previous Balance
Payment(s) Received
Balance as of 4/21/16

2

$0.00

Current Electric Charges
Current Taxes and Fees

130.63
9.13

Total Current Charges as of 4/21/16

$139.76

Total Amount Due

$139.76

DUE DATE

$139.76

121.16
-121.16

EVERYTHING INCLUDED
IN YOUR NEW BILL

3000-0000-0001

AMOUNT DUE

5/18/16

Account Name:
Service Address:

JOHN SMITH
100 Deer Crossing Way
LEXINGTON KY

Online Payments:
Telephone Payments:

lge-ku.com
(859) 255-0394, press 1-2-3
24 hours a day; $2.25 fee
(859) 255-0394
M-F, 7am-7pm ET
1 Quality Street
Lexington, KY 40507
M-F, 8am-5pm ET

Customer Service:
Walk-in Center:

3

Easy-to-find the Amount Due and Payment Due Date.
1   

Next read will occur 5/19/16 - 5/21/16 (Meter Read Portion 14)

2

  Easy-to-read Billing Summary that shows your previous
balance, payments received and your current charges.

3

  The account name and service address along with
ways to pay and contact information for Customer
Service. We also include the date range for your next
meter reading.

4

  A detailed breakdown of your electric usage and charges.

5

  Average temperature, usage and charges compared to the
same time last year.

6

  
NEW! We’re now including a chart, so you can see how
your monthly usage compares to previous months, as well
as for the same time period the previous year.

7

  
NEW! Daily average gives you even more information,
like a daily average of your monthly cost for energy and
the daily average outside temperature.

8

  A breakdown of taxes and fees included in your bill.

9

  Billing Information gives you relevant information about
your bill, account and service.

CURRENT USAGE
ELECTRIC
Meter Reading Information

Meter # L200000

Actual (R) kWh Reading on 4/21/16
Previous (R) kWh Reading on 3/20/16
Current kWh Usage
Meter Multiplier
Metered kWh Usage

10109
8698
1411
1
1411

CURRENT CHARGES
ELECTRIC

Rate: Residential Service

Basic Service Charge
Energy Charge ($0.07744 x 1,411 kWh)
Electric DSM ($0.00376 x 1,411 kWh)
Fuel Adjustment ($0.00007 x 1,411 kWh)
Environmental Surcharge (3.950% x $125.43)
Home Energy Assistance Fund Charge
Total Charges

4

10.75
109.27
5.31
0.10
4.95
0.25
$130.63

Please return only this portion with your payment. Make checks payable to KU and write your account number on your check.

$139.76

Account # 3000-0000-0001
Service Address: 100 Deer Crossing Way

31.59

Account # 3000-0000-0001

1202

1411

CURRENT
BILLING
PERIOD

6
1319

1019

44.09

1011

Avg. Electric Usage per Day (kWh)

1653

55°
53°
PO Box 9001954
32
32
Louisville, KY 40290-1954
Avg. Electric Charges per Day
$4.08
$3.02

1270

LAST YEAR

Average Temperature
Number of Days Billed

1045

THIS YEAR

JOHN SMITH
100 DEER CROSSING WAY
ELECTRIC (kWh)
LEXINGTON, KY 40509-0000

MONTHLY USAGE

1180

#926190001 5#

5

1573

BILLING PERIOD AT-A-GLANCE

1538

Page 2

1247

$143.95

1643

Amount Due 5/18/16
After Due Date, Pay this Amount:
WinterCare Donation:
Total Amount Enclosed:

02030000000000100000000143950000001397600000000000028
APR

Taxes & Fees
Rate Increase For School Tax (3.00% x $130.38)
Franchise Fee-Lexington-Fayette (4.00% x $130.38)
Total Taxes and Fees

AVERAGE

7

u
u

JUN

JUL

$4.19

AUG

SEP

OCT

NOV

DEC

JAN

FEB

MAR

APR

2015 2016
52°

62°

72°

75°

73°

74°

63°

45°

40°

33°

28°

38°

55°

3.02

3.44

5.28

4.81

4.90

4.68

3.58

3.40

3.90

3.66

3.42

4.53

4.08

8

BILLING INFORMATION
Late Payment Charge
Late Charge to be Assessed After Due Date

MAY

3.91
5.22
$9.13

9

Rate Schedules
For a copy of your rate schedule, visit lge-ku.com or call our Customer Service Department.
xxx

CUSTOMER SERVICE
lge-ku.com

OFFICE USE ONLY
MRU14311654, G000000
P121.16
PF:Y eB:P

A CLOSER LOOK AT
YOUR NEW BILL.
It’s All About You

Attachment to Response to AG-2 Question No. 9(b)
Page 123 of 170
Scott

 NEW FEATURES TO HELP
YOU BETTER UNDERSTAND
YOUR ENERGY USE
Your new bill is filled with information
BILLING SUMMARY
to Previous
giveBalance
you a clear view of exactly121.16
what
Payment(s) Received
-121.16
your
monthly balance includes so $0.00
you
Balance as of 4/21/16
can
better
manage your energy usage.
Current
Electric Charges
130.63
Current Taxes and Fees

9.13

Total Current Charges as of 4/21/16

$139.76

Total Amount Due

$139.76

Mailed 4/29/16 for Account #

AMOUNT DUE

$139.76

3000-0000-0001
DUE DATE

5/18/16

Account Name:
Service Address:

JOHN SMITH
100 Deer Crossing Way
LEXINGTON KY

Online Payments:
Telephone Payments:

lge-ku.com
(859) 255-0394, press 1-2-3
24 hours a day; $2.25 fee
(859) 255-0394
M-F, 7am-7pm ET
1 Quality Street
Lexington, KY 40507
M-F, 8am-5pm ET

Customer Service:
Walk-in Center:

Next read will occur 5/19/16 - 5/21/16 (Meter Read Portion 14)

The following line items can be found under the
Electric Charges section of your bill (shown at left).

CURRENT USAGE
ELECTRIC
Meter Reading Information

Meter # L200000

Actual (R) kWh Reading on 4/21/16
Previous (R) kWh Reading on 3/20/16
Current kWh Usage
Meter Multiplier
Metered kWh Usage

10109
8698
1411
1
1411

CURRENT CHARGES
ELECTRIC

Rate: Residential Service

Basic Service Charge
Energy Charge ($0.07744 x 1,411 kWh)
Electric DSM ($0.00376 x 1,411 kWh)
Fuel Adjustment ($0.00007 x 1,411 kWh)
Environmental Surcharge (3.950% x $125.43)
Home Energy Assistance Fund Charge
Total Charges

10.75
109.27
5.31
0.10
4.95
0.25
$130.63

All of these charges have been reviewed and approved by the
Kentucky Public Service Commission.
•B
  asic Service Charge – A fixed charge to help defray the
costs for meter reading and processing, meter maintenance,
and billing and payment processing.
•E
  nergy Charge – The per unit cost (rate) multiplied by the
amount of electricity (kilowatt hours – kWh) you used.
•E
  lectric DSM – Charges to cover costs associated with energy
efficiency programs, including Demand Conservation, Home
Energy Analysis, Fridge and Freezer Recycling programs, and
weatherization efforts.

Please return only this portion with your payment. Make checks payable to KU and write your account number on your check.

Amount Due 5/18/16
After Due Date, Pay this Amount:
WinterCare Donation:
Total Amount Enclosed:

$139.76

$143.95
HERE’S WHAT’S NEW

  
Daily averages for usage, cost,
and temperatures each month.

  13-month history so you can compare
your usage to previous months.
PO Box 9001954

•E
  lectric Fuel Adjustment – A charge or credit applied to your
bill
based on rising (charge) or falling (credit) fuel costs
Account # 3000-0000-0001
associated
with
The rate can change
Service
Address:
100 generating
Deer Crossingelectricity.
Way
monthly, and it is calculated as a cost (or credit) per kilowatt
hour (kWh) used.
#926190001 5#

•E
  nvironmental Surcharge – A charge that pays for
JOHN SMITH
government-mandated
emission controls, such as the cost of
100 DEER CROSSING WAY
LEXINGTON, KY 40509-0000
baghouses,
scrubbers and other equipment that minimize
environmental impact.

40290-1954center
  The addressLouisville,
of theKYwalk-in
closest to your home.

 

•H
  ome Energy Assistance Fund Charge – A monthly per meter
charge that provides energy assistance to customers in need
who meet specified income guidelines and program criteria.
Audible PDFs for the visually impaired.
02030000000000100000000143950000001397600000000000028

Attachment to Response to AG-2 Question No. 9(b)
Page 124 of 170
Scott

 Power Source
Readership Study
03.25.2016

P R E P A R E D

Power Source Readership Survey

B Y

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 125 of 170
Scott

 Agenda

 Background and Objectives

3

 Methodology

4

 Executive Summary

6

 Detailed Findings
 Awareness and Readership

9

 Satisfaction with Power Source

16

 Topics of Interest

28

 E-Newsletter

32

 Communication Preference

35

 Demographics

40

 Online Panel Study

43

Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 126 of 170
Scott

 Background and Objectives
Background
In 2012, LG&E/KU conducted a Power Source readership study with a third party vendor
among both paper and paperless bill customers. With the upcoming bill redesign and recent
move to a new vendor for the newsletter, LG&E/KU wanted to update this research.

Objectives
The overall objective of this study is to understand readership of both the paper and
electronic newsletter. Specifically, the study evaluates:





Overall awareness of the newsletter
Frequency of readership
Preferred newsletter topics
Preferred communication vehicle

Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 127 of 170
Scott

 Methodology
LG&E/KU provided customer lists for both paper and paperless bill customers. From these
lists sample was pulled proportionally by Utility for surveying.
Paper bill customers were surveyed via telephone and paperless bill customers were sent an
email invitation with a link to the internet survey. Data collection for this research was
conducted from mid-February through early March 2016. The survey was approximately 5
minutes in length.
Phone data collection, among paper bill customers, was conducted Monday-Friday during
the evening from 5pm-9pm and as needed on Saturday 9am-5pm. Paperless bill customers
had 24/7 access to the online survey.

Quotas were set in order to achieve a 95% confidence level with a 2% to 3% margin of error.
Additionally, phone quotas were set by Utility (LG&E and KU/ODP) to ensure accurate
representation.
Statistical testing was conducted at the 95% confidence level, and significant differences are
noted.

Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 128 of 170
Scott

 Methodology
A breakdown of survey completes by Utility and bill type (paper vs. paperless) is outlined
below:

Total

Paper
(Phone Survey)

Paperless
(Online Survey)

Total Respondents

3,190

1,000

2,190

LG&E

1,604

500

1,104

KU/ODP

1,586

500

1,086

Aware and Read Newsletter

1,634

662

972

LG&E

825

330

495

KU/ODP

809

332

477

Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 129 of 170
Scott

 Executive Summary

Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 130 of 170
Scott

 Conclusions
More paper bill customers are aware of the Power Source newsletter (75%) than
paperless (52%), suggesting an opportunity to increase awareness.
• Younger customers are least aware, presenting the greatest opportunity.

Customer satisfaction with the newsletter is 7.5 on a 10pt scale, although paper bill
customers are more satisfied (7.9) than paperless bill customers (7.3).
• Paper bill customers are also more likely to read Power Source. These customers tend to be
older and more satisfied with the newsletter.

Those customers who read the newsletter frequently and in-depth are most satisfied.
This is likely because they find the articles interesting and helpful.
• The challenge is providing articles that appeal to more customers in order to improve
readership.

Although customers are interested in a wide range of topics, they are primarily
interested in learning how to save money on their utility bill. This includes
understanding things that impact their bill, energy efficiency programs and renewable
energy options.
Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 131 of 170
Scott

 Conclusions
Most paperless bill customers are familiar with e-newsletters and would be interested in
receiving one once a month. Gaining adoption from paper bill customers is less likely
due to low familiarity and interest.
Communication preferences vary across the utility customer base.
• Paperless bill and younger customers generally prefer email communications.
• Paper bill customers prefer more traditional bill inserts, other mailed communications and
automated telephone calls.

Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 132 of 170
Scott

 Awareness and
Readership

Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 133 of 170
Scott

 Awareness
Over half of customers surveyed were aware of the Power Source newsletter, similar for both LG&E and KU.
However, paper bill customers, who receive Power Source by mail, were more aware than paperless bill
customers.

Power Source Awareness
75% +
60%

59%

60%
52%

Total

LG&E

KU

Paper

Paperless

Q1. [IF PHONE] Are you aware of the Power Source newsletter that [LG&E, KU] includes with your monthly bill?
[IF ONLINE] Are you aware of the Power Source newsletter that [LG&E, KU/ODP] includes as a link with your monthly online bill?
Note: +/- indicates significant difference at 95% confidence level

Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 134 of 170
Scott

 Awareness
Older customers were more aware of the Power Source newsletter than younger customers. Additionally, these
older customers were more likely to receive the paper version of Power Source.

Power Source Awareness – By Age
71%ABCD
60%

61%AB

61%AB

54%A
47%

Total

18-34
(A)

35-44
(B)

45-54
(C)

55-64
(D)

65+
(E)

Paper (a)

20%

13%

15%

18%

30%b

Paperless (b)

20%

17%a

17%

23%a

21%

Q1. [IF PHONE] Are you aware of the Power Source newsletter that [LG&E, KU] includes with your monthly bill?
[IF ONLINE] Are you aware of the Power Source newsletter that [LG&E, KU/ODP] includes as a link with your monthly online bill?
Letters indicate significant difference at 95% confidence level

Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 135 of 170
Scott

 Readership
Just over one-third of customers surveyed reported they read the Power Source newsletter often (every month
or most months), similar for both LG&E and KU. However, paper bill customers were more likely than paperless
to read Power Source regularly.

Frequency of Power Source Readership
Among those aware of the newsletter
Often

Sometimes

35%

35%

36%

27%

27%

26%

Rarely/Never

42% +

31%

26%
27%

38%

38%

38%

Total

LG&E

KU

43%

31% -

Paper

Paperless

Q2. How often do you read the Power Source newsletter?
Note: +/- indicates significant difference at 95% confidence level

Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 136 of 170
Scott

 Readership
Older customers tend to read Power Source more frequently, with nearly half reporting they read the newsletter
every month or most months. Paper customers in the youngest and oldest age groups were more likely to read
Power Source than those receiving the online version.

Frequency of Power Source Readership* - % Often by Age
47%ABCD

37%AB

32%A

28%A
20%
A

B

C

D

E

18-34

35-44

45-44

55-64

65+

Paper

30%

27%

Paperless

34%
26%

31%

58%
36%

37%

37%

14%

18-34

35-44

45-44

55-64

65+

Q2. How often do you read the Power Source newsletter? *Among those aware of Power Source
Letters indicate significant difference at 95% confidence level

Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 137 of 170
Scott

 Readership
Very few customers said they read every article in a typical Power Source issue, similar between LG&E and KU.
Depth of readership for paper and paperless customers was similar with just under half reading the majority of a
typical issue; however, paper bill customers were more likely to read every article.

Depth of Power Source Readership
Among those who read the newsletter
Every article

More than half the articles

Less than half the articles

Maybe one article

Don't know

8%

10%

10%

9%

13% +

33%

32%

34%

30%

34%

24%

24%

25%

27% +

23%

23%

25%

22%

10%

9%

10%

Total

LG&E

KU

43%

42%

20%
28% +
15%
2% Paper

Paperless

Q4. Thinking of a typical Power Source issue, how many articles do you read?
Note: +/- indicates significant difference at 95% confidence level

Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 138 of 170
Scott

 Readership
Older customers were more likely to read the majority of the articles in a typical Power Source issue. Within age
groups, depth of readership was similar between the paper and electronic versions of the newsletter.

Depth of Power Source Readership* - % Read Majority by Age**
41%A

35%

27%

48%AB

49%ABC

A

B

C

D

E

18-34

35-44

45-44

55-64

65+

Paper

Paperless
46%

44%
29%

33%

36%

49%

53%
45%

37%

26%

18-34

35-44

45-44

55-64

65+

Q4. Thinking of a typical Power Source issue, how many articles do you read? *Among those who read Power Source
**Majority defined as reading every article or more than half the articles
Letters indicate significant difference at 95% confidence level

Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 139 of 170
Scott

 Satisfaction with
Power Source

Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 140 of 170
Scott

 Overall Satisfaction
In general, customers who read Power Source rated their satisfaction with the newsletter at a 7.5 out of 10. KU
customers rated their satisfaction higher than LG&E customers, although both were more satisfied with the
paper version of the newsletter. Ratings among paperless customers were more similar between LG&E and KU.

Overall Satisfaction with Power Source
Among those who have read the newsletter

7.5

7.3 -

Total

LG&E

7.8

7.9 +

KU

Paper

Paperless

LG&E

7.5 +

7.2

KU

8.2 +

7.4

7.3

Q3. How satisfied are you overall with the Power Source newsletter?
Note: +/- indicates significant difference at 95% confidence level

Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 141 of 170
Scott

 Overall Satisfaction
Customers who were generally satisfied with the newsletter found it to be informative.

Reason for Overall Satisfaction Rating – Neutral/Satisfied (Rating 6-10)
Among those who have read the newsletter
Paperless (n=329)

Paper (n=498)

Provides helpful information/informative
Very satisfied with newsletter
Has good content
Rarely read the newsletter
Information is interesting
Provides information that is not useful
Neutral opinion of newsletter
Does not include interesting information
Does not provide enough information
Information is repetitive
Other
Q3a. Why did you give this rating?
Note: +/- indicates significant difference at 95% confidence level
Note: Base for percentages excludes refused responses

Don't know

Power Source Readership Survey

33% -

40%

7%

12% +
12%
10%
12%
8%
10%
6%
5%
4%
2%
3%
4%
2%
2%
2%
1%
1%
7%
12% +
2%
10% +
*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 142 of 170
Scott

 Overall Satisfaction
About one-third of both paper and paperless bill customers rated their satisfaction with Power Source low
because they rarely read it. Paperless bill customers also thought that the newsletter did not include interesting
information.

Reason for Overall Satisfaction Rating – Dissatisfied (Rating 1-5)
Among those who have read the newsletter
Paperless (n=96)

Paper (n=119)
33%
32%

Rarely read the newsletter
Neutral opinion of newsletter

5%

13%
9%
10%
7%
8%

Provides helpful information/informative
Provides information that is not useful
Does not include interesting information
Has good content
Does not provide enough information
Very satisfied with newsletter
Information is interesting
Information is repetitive
Other
Q3a. Why did you give this rating?
Note: +/- indicates significant difference at 95% confidence level
Note: Base for percentages excludes refused responses

Power Source Readership Survey

Don't know

7% -

18%

4%
3%
4%
2%
1%
2%
0%
2%
4%
0%
7%
9%
7%

16% +

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 143 of 170
Scott

 Overall Satisfaction
As seen on slide 12, readership is lower among paperless bill customers, which aligns with several of the
comments provided. Some reference receiving and reading Power Source by mail in the past and then forgetting
about it when they switched to paperless billing. Paper bill customers provided more positive comments.

Paperless

Paper

(n=539)

(n=641)

I seldom read it. When it was enclosed with the
paper bill, I always read it. I simply forget about it.
Overall Sat=6
Code: Rarely read the newsletter

When I received it in the mail I was more apt to look
at it than when I received it through the internet.
I fail to look it up.
Overall Sat=10
Code: Rarely read the newsletter

Every time that I read, it is very informative. Maybe
it could be more interesting. I like the energy saving
tips.
Overall Sat=9
Code: Informative and Does not include interesting
information

I like to see what they are saying every month. I just
like to know how much we are spending.
Overall Sat=9
Code: Information is interesting

I used to read it when I got a paper statement and
found it very useful and informative. Since I have
switched to paperless billing. I usually forget to read
it.

It is very informative, very educational, and very
easy to read. It’s concise and does not take a long
time to read.

Overall Sat=8
Codes: Informative and Rarely read the newsletter

Overall Sat=10
Code: Informative

I am interested in my energy bill and supporting
topics. I like to see innovations no matter who does
them.

Well, it think it gives you a lot of ideas of how you
can save money and where you stand with everyone
else.

Overall Sat=10
Code: Information is interesting

Overall Sat=10
Code: Has good content

Q3a. Why did you give this rating?

Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 144 of 170
Scott

 Overall Satisfaction
Overall Satisfaction with Power Source trends downward as frequency and depth of readership falls off. The gap
between paper and paperless ratings is most pronounced for customers reading only one article of the
newsletter.

Overall Satisfaction with Power Source by Readership
Among those who have read the newsletter
Paperless
Paper

Frequency of Readership

10.0

Depth of Readership

9.5
8.4
8.1

8.7
8.5
7.9

9.0

8.5

8.5

8.1

8.0
7.4

7.2

7.2

6.8

6.5

7.0
6.5

5.9

5.8

7.5

6.0
5.5
5.0

Often

Sometimes Rarely/Never

Every
article

More than
half
the articles

Less than
half
the articles

Maybe
one article

Q3. How satisfied are you overall with the Power Source newsletter?
Q2. How often do you read the Power Source newsletter?
Q4. Thinking of a typical Power Source issue, how many articles do you read?

Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 145 of 170
Scott

 Overall Satisfaction
Across age groups, customers who receive the paper version of Power Source rated their satisfaction higher than
those who receive the online version, with the largest gap among younger customers.

Overall Satisfaction with Power Source – by Age
Among those who have read the newsletter
Paperless

Paper

10.0
9.5
9.0
8.5

8.1
7.6
7.1

7.0

7.6
7.2

7.7
7.3

8.1

8.0

7.6

7.5
7.0
6.5
6.0
5.5
5.0

18-34

35-44

45-54

55-64

65+

Q3. How satisfied are you overall with the Power Source newsletter?

Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 146 of 170
Scott

 Overall Satisfaction
Among paper bill customers, higher education tends to correspond with lower satisfaction, suggesting the
current Power Source newsletter is not meeting their needs. Paperless bill customers without any college rated
their Overall Satisfaction much lower than paper customers.

Overall Satisfaction with Power Source – By Education
Among those who have read the newsletter
Paperless

8.3

Paper

8.3
7.9
7.4

7.7
7.3

Some college

College grad

7.4
7.3

6.8

*
Some high school

High school grad

Post-graduate

Q3. How satisfied are you overall with the Power Source newsletter?
*Base size insufficient to report for Paperless some “Some high school” (n=3)

Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 147 of 170
Scott

 Topic Relevance Satisfaction
In general customers who read Power Source rated their satisfaction with the relevance of topics included at a
7.5 out of 10, in line with Overall Satisfaction. KU customers rated their satisfaction higher than LG&E
customers. Higher ratings among customers receiving the paper version of the newsletter were driven by KU
customers.

Satisfaction with Topic Relevance
Among those who have read the newsletter

7.5

7.3 -

Total

LG&E

7.7

7.7 +

KU

Paper

Paperless

7.5

7.2

7.9 +

7.5

LG&E
KU

7.4

Q5. How satisfied are you with the relevance of the topics included in the Power Source newsletter?
Note: +/- indicates significant difference at 95% confidence level

Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 148 of 170
Scott

 Topic Relevance Satisfaction
Customers who frequently read Power Source rated their satisfaction with the relevance of topics similarly
whether they received the paper or electronic version. Similar to Overall Satisfaction, paperless customers who
read only one article rated topic relevance lower than those who received the paper version.

Satisfaction with Topic Relevance by Readership
Among those who have read the newsletter
Paperless
Paper

Frequency of Readership

10.0

Depth of Readership

9.5
9.0

8.7
8.2
7.8

9.0

8.4
8.3

8.5
8.0
7.1
6.8

7.2
6.4
6.0

7.5
6.9

7.0
6.5

5.8

6.0
5.5
5.0

Often

Sometimes Rarely/Never

Every
article

More than
half
the articles

Less than
half
the articles

Maybe
one article

Q5. How satisfied are you with the relevance of the topics included in the Power Source newsletter
Q2. How often do you read the Power Source newsletter?
Q4. Thinking of a typical Power Source issue, how many articles do you read?

Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 149 of 170
Scott

 Topic Relevance Satisfaction
Paper and paperless billing customers in the older age groups tend to rate their satisfaction with topic relevance
more similarly than younger customers.

Satisfaction with Topic Relevance – by Age
Among those who have read the newsletter
Paperless

Paper

10.0
9.5
9.0
8.5

8.1
7.6
7.2

7.4

7.1

7.5
7.3

7.8
7.7

8.0
7.5
7.0
6.5
6.0
5.5
5.0

18-34

35-44

45-54

55-64

65+

Q5. How satisfied are you with the relevance of the topics included in the Power Source newsletter?

Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 150 of 170
Scott

 Topic Relevance Satisfaction
Satisfaction with topic relevance by education level mirrors the trend seen with Overall Satisfaction, with lower
satisfaction among paper bill customers corresponding with higher education.

Satisfaction with Topic Relevance – By Education
Among those who have read the newsletter
Paperless

8.2

8.1

7.7
7.6

Paper

7.5
7.3

7.5

College grad

Post-graduate

6.8

*
Some high school

High school grad

Some college

Q5. How satisfied are you with the relevance of the topics included in the Power Source newsletter?
*Base size insufficient to report for Paperless some “Some high school” (n=3)

Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 151 of 170
Scott

 Topics of Interest

Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 152 of 170
Scott

 Topics of Interest
Over three-fourths of customers surveyed expressed an interest in Power Source topics regarding things that
impact their utility bill, similar across age groups. Other areas of interest included Energy Efficiency programs
and renewable energy options, suggesting customers are most interested in topics that impact their energy
costs. Younger customers were more likely to express no interest in any of the topics listed.

Topics of Interest
Total

77%

Things that impact your utility bill

59%

Energy Efficiency programs

53%

Renewable energy options for the consumer

18-34

35-44

45-54

55-64

65+

76%

78%

79%

77%

78%

54%

59%

61%

61%

62%

53%

51%

55%

53%

55%

Renewable energy options for Utility

42%

43%

41%

41%

41%

43%

How utility plans for the future

41%

35%

37%

43%

40%

48%

Safety around electricity and natural gas

39%

28%

31%

41%

41%

47%

New Technologies

38%

33%

33%

41%

37%

46%

Other programs and services offered by utility

33%

24%

30%

38%

36%

37%

Environmental regulations

32%

28%

26%

28%

33%

41%

23%

24%

27%

29%

35%

18%

17%

22%

17%

23%

15%

11%

8%

9%

7%

28%

Gas and Electric Reliability
Community involvement activity
None of the above

19%
10%

Q6. Which of the following newsletter topics are of interest to you?
Circle indicates significant difference at 95% confidence level versus all other age groups

Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 153 of 170
Scott

 Topics of Interest
Customers who receive a paper bill expressed interest in a greater variety of Power Source topics than paperless
customers; however, the difference in methodology between the groups (Phone vs. Online) is likely contributing
to this.

Topics of Interest
Paperless

Paper

74%

Things that impact your utility bill

53%

Energy Efficiency programs

69%

26%

Safety around electricity and natural gas

67%

30%

How utility plans for the future

65%

27%

New Technologies

63%

21%

Other programs and services offered by utility

60%
33%

Renewable energy options for Utility

16%

Gas and Electric Reliability

12%

Community involvement activity

6%

60%
56%

21%

Environmental regulations

None of the above

74%

46%

Renewable energy options for the consumer

85%

55%
36%

13%

Q6. Which of the following newsletter topics are of interest to you?

Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 154 of 170
Scott

 Topics of Interest
When asked for any other newsletter topics of interest, the majority of customers surveyed chose not to provide
a response. Among those who did respond, another third provided a comment stating nothing or none. Some
customers made valuable suggestions, mostly regarding more detailed information on energy usage, Energy
Efficiency and/or ways to better understand their LG&E/KU bill.
% Refused
Paper

84%

Paperless

86%

I am interested in energy efficiency
measures like energy audits, insulation,
air infiltration sealing etc. However, I am
unsure of what private contractors are
available, nor how much they charge for
such services. If LG&E could standardize
or approve such services, it would be
easier to make decisions about energy
efficiency measures.

It's hard to publish a newsletter with topics that are
relevant to all the people all the time. Most folks need
specific information when they need specific information.
Given the available technology, you might invest your
communications dollars better in an interactive website
that 'pops' with each monthly bill.

How to access interval and demand data
in order to appropriately select from the
three current residential rates available.

What to do in the case of an emergency.

Political influences on the utility
industry, including KU’s support
of political parties. Curious if KU
makes donations to any political
organizations.

Q6a. Are there any other newsletter topics that are of interest to you?

Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 155 of 170
Scott

 E-Newsletter

Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 156 of 170
Scott

 E-Newsletter
Nearly two-thirds of customers surveyed were familiar with the concept of an e-newsletter, with paperless
customers much more familiar than paper. Many customers familiar with e-newsletters were interested in
receiving this format. Not surprisingly, customers who were unfamiliar expressed less interest.

Are you familiar with
e-newsletters?
Yes

No

How interested are you in receiving an
e-newsletter from LG&E and KU?

Don't know

Familiar with e-newsletters
Very Interested

15%

44% Somewhat Interested

66%

76%

49%

Not Interested

36%

Unfamiliar with e-newsletters
55% +

Very Interested

32%
2%
Total

21%
1% Paper

9%

Somewhat Interested

32%

3%
Paperless

Not Interested

60%

Q7. Are you familiar with e-newsletters?
Q.8 How interested are you in receiving an e-newsletter from LG&E/KU?
Note: +/- indicates significant difference at 95% confidence level

Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 157 of 170
Scott

 E-Newsletter
Paperless billing customers are significantly more interested in receiving an e-newsletter than paper customers;
however, only 14% of paperless customers are very interested. Of those who are very interested, preference
towards a monthly e-newsletter is similar for both paper and paperless customers.

How interested are you in receiving an
e-newsletter from LG&E and KU?
10% -

14%

How often would you be interested in
receiving an e-newsletter?
Among customers very interested in
receiving an e-newsletter
Paperless

Very Interested

73%

Once a month

76%

53%

Somewhat
Interested
Not Interested

Paper

24% -

18%

Twice a month

66% +

14%
33%
Once a week

9%
11%

Paper

Paperless

Q.8 How interested are you in receiving an e-newsletter from LG&E/KU?
Q.9 How often would you be interested in receiving an e-newsletter?
Note: +/- indicates significant difference at 95% confidence level

Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 158 of 170
Scott

 Communication
Preference

Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 159 of 170
Scott

 Method of Communication
Preferred method of communication varies between paper and paperless customers. Paperless customers
prefer more digital methods of communication, such as e-mail and the utility website, while paper customers
like mail and phone communications.

Preferred Method of Communication
Paperless
E-mail
Utility website

26%

4%

22%
11%
16%

Mail (separate from bill)
News media

3%

Bill message

3%

Newspaper
Automated phone call
Phone Call
In person
Don't know

63%

18%

Text message

Advertisements

82%

35%

Bill Insert (with bill)

Social media

Paper

29%

11%
11%

10%
2%
6%
3%
5%
2%
2%

26%

0%
3%
0%
2%
4%
4%

Q.10 How do you prefer to receive information and communications from LG&E and KU?

Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 160 of 170
Scott

 Method of Communication
E-mail and Bill Inserts were the top two preferred methods of communication across age groups, although e-mail
preference declines with age.

Top Three Preferred Communication Methods – by Age
18-34

35-44

77%

45-54

65 or older

55-64

74%
68%

68%
56%
43%

32%

35%

30%
22%

22%

32%
21%

19%

21%

Q.10 How do you prefer to receive information and communications from LG&E and KU?

Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 161 of 170
Scott

 Method of Communication
Preferences vary across age groups for paper bill customers, with younger customers expressing a preference
towards electronic communications while older customers prefer more traditional bill inserts.

Top Three Preferred Communication Methods – by Age
Paper Bill Customers
18-34

35-44

45-54

65 or older

55-64

73%
67%

64%

64%

57%

53%

50%
38%

36%

36%
28%

31%

27%

27%

22%

Q.10 How do you prefer to receive information and communications from LG&E and KU?

Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 162 of 170
Scott

 Method of Communication
Paperless bill customers across age groups overwhelmingly prefer to receive communications via email.

Top Three Preferred Communication Methods – by Age
Paperless Bill Customers
18-34

35-44

83%

45-54

83%

24%

23%

81%

21%

83%

81%

29%

27%

65 or older

55-64

21%

24%

21%

24%

23%

Q.10 How do you prefer to receive information and communications from LG&E and KU?

Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 163 of 170
Scott

 Demographics

Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 164 of 170
Scott

 Demographics
Customers who choose paperless billing tend to be higher educated with higher income than those choosing to
receive a paper bill.

LG&E

KU

Paper

Paperless

1,604

1,586

1,000

2,190

1st through 8th grade

0% -

1%

2% +

0%

Some high school

2% -

3%

8% +

0%

High school graduate or equivalent

12% -

15%

26% +

8%

22%

22%

20%

23%

35% +

30%

28% -

35%

Graduate/post-graduate school

27%

25%

12% -

33%

Prefer not to answer

2%

3%

5% +

2%

$40,000 or less

26% -

31%

45% +

22%

Over $40,000

55% +

50%

37% -

59%

19%

19%

18%

19%

Base

Education

Some college/technical school
College graduate

Income

Prefer not to answer

Note: +/- indicates significant difference at 95% confidence level for LG&E vs. KU and Paper vs. Paperless

Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 165 of 170
Scott

 Demographics
Almost one-third of paper bill customers surveyed are age 65 or older.

LG&E

KU

Paper

Paperless

1,604

1,586

1,000

2,190

18-34

20%

20%

20%

20%

35-44

16%

16%

13% -

17%

45-54

16%

16%

15%

17%

55-64

22%

21%

18% -

23%

65+

25%

23%

30% +

21%

Prefer not to answer

2% -

3%

3% +

2%

Male

48%

45%

49%

45%

Female

50%

52%

51%

52%

Prefer not to answer

2%

3%

-

3%

Base

Age

Gender

Note: +/- indicates significant difference at 95% confidence level for LG&E vs. KU and Paper vs. Paperless

Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 166 of 170
Scott

 Online Panel Study
During the same timeframe that Bellomy Research conducted
the phone (paper bill) and internet (paperless bill) newsletter
readership studies, LG&E/KU also ran the survey among
customers who are participating in the Online Residential Panel.
Following is a comparison of those results.

Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 167 of 170
Scott

 Online Panel Study
Awareness among paperless customers was identical for both the online panel and Readership studies. Panel
members who receive a paper bill reported higher awareness than those surveyed for the Readership Study,
possibly due to higher engagement with the utility for panel members. Overall Satisfaction with Power Source
was slightly higher for the Readership Study.

Power Source Awareness
Online Panel Study

Readership Study
(Bellomy Research)

91%
75%

52%

Paper

Paperless

52%

Overall Satisfaction
Bellomy

7.5

Online Panel

7.1

Paper

Paperless

Q1. [IF PAPER] Are you aware of the Power Source newsletter that [LG&E, KU] includes with your monthly bill?
[IF PAPERLESS] Are you aware of the Power Source newsletter that [LG&E, KU/ODP] includes as a link with your monthly online bill?

Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 168 of 170
Scott

 Online Panel Study
Topics of interest were similar for both studies, with learning more about things that impact their utility bill at
the top of the list.

Topics of Interest
Readership Study (Bellomy Research)

Online Panel Study

77%
83%

Things that impact your utility bill
Energy Efficiency programs
Renewable energy options for the consumer
Renewable energy options for Utility

33%

41%
35%
39%
34%
38%
32%
33%
30%
32%
24%
28%

How utility plans for the future
Safety around electricity and natural gas
New Technologies
Other programs and services offered by utility

Environmental regulations
Gas and Electric Reliability
Community involvement activity
None of the above

59%
60%
53%
48%
42%

4%

16%
19%
18%
10%

Q6. Which of the following newsletter topics are of interest to you?

Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 169 of 170
Scott

 Online Panel Study
Awareness and interest in e-newsletters was similar for online panel members and paperless customers
surveyed for the Readership Study.

e-newsletters
Readership Study

Online Panel Study

Among Paperless Bill Customers
(Bellomy Research)
76%

75%
69%

67%

% Familiar

Very
14%

Very
18%

Somewhat
53%

Somewhat
51%

% Interested

% Familiar

% Interested

Q7. Are you familiar with e-newsletters?
Q.8 How interested are you in receiving an e-newsletter from LG&E/KU?

Power Source Readership Survey

*CONFIDENTIAL: FOR INTERNAL USE ONLY

Attachment to Response to AG-2 Question No. 9(b)
Page 170 of 170
Scott

 Response to AG-2 Question No. 10
Page 1 of 2
Arbough/Scott

KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 10
Responding Witness: Daniel K. Arbough / Valerie L. Scott
Q-10.

Refer to the response to AG-1-50(e), Charges from LG&E and KU Services
Company.
a. Why are affiliate charges for CWIP (account 107) projected to increase from
$56.161 million in the base period to $108.409 million in the Forecast Test
Period?
b. Why are there no affiliate charges in the Forecast Test Period in account 165,
Prepayments (but $14.025 million in the base period)?
c. Why are affiliated charges for Maintenance of Overhead lines (account 571)
increasing from $2.961 million in the base period to $11.532 million in the
Forecast Test Period?
d. Why are affiliated charges for Maintenance of Meters (account 597) zero in
the base period and projected to be $1.443 million in the Forecast Test Period?
e. What advertising is included in the base period and Forecast Test Period
amounts for each of these accounts (1) account 910, (2) account 913 and (3)
account 930.1?
f. Why are Miscellaneous General Expenses in account 930.2 increasing from
zero in the base period to $5.041 million in the Forecast Test Period?

A-10.
a. See the response to KIUC 1-38.
b. The amounts in the base period are prepayments primarily for IT software
maintenance contracts and the transmission Reliability Coordinator which
occurred during March 2016 – August 2016. The Companies do not forecast
prepayments.

 Response to AG-2 Question No. 10
Page 2 of 2
Arbough/Scott

c. See the response to KIUC 1-38.
d. See the response to KIUC 1-38.
e. No advertising expense is included in the base period or in the forecast test
period amounts for account 910. Accounts 913 and 930.1 are not included in
base rates.
f. Account 930 was shown in total in the response to AG 1-50(e). As shown in
the response to KIUC 1-38, the Miscellaneous General Expenses in account
930.2 are $4,652,659 in the Base Period and they increased to $5,040,577 in
the Forecast Test Period. The increase is primarily due to higher research and
development expenses.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 11
Responding Witness: Daniel K. Arbough
Q-11.

Refer to the response to AG-1-50(d). Provide an itemization showing what is
included in the forecasted PPL Services Corporation charges to KU for each
account:
a. account 920
b. account 921
c. account 926

A-11.

See table below for a-c.
Account 920
IT Joint Initiatives
Account 921
Audit - PCAOB Fees
Office of Compliance
Credit Services
Financial Statement Reporting Software
Hyperion Financial Management Software
Insurance Services
Internal Reporting
Investor Relations
IT Joint Initiatives
Office of General Counsel
Pension/Investments
UI Planner Software
Wall Street Software
Account 926
IT Joint Initiatives

139,317

37,118
58,208
7,891
3,514
9,676
77,465
172,549
210,283
78,947
470,722
251,821
10,486
37,440
1,426,120
100,896

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 12
Responding Witness: Kent W. Blake
Q-12.

Refer to the response to AG-1-51. Identify and explain the best practices that were
exchanged and quantify the savings to KU that resulted from the exchange of best
practices.

A-12.

The most recent identification and explanation of best practice exchanges is set
forth in the October 31, 2016 update on the adoption and implementation of best
practices at the Companies pursuant to Appendix C, Regulatory Commitment No.
12 of the September 30, 2010 Order in Case No. 2010-00204. A copy is available
at (http://psc.ky.gov/PSC_WebNet/ViewCaseFilings.aspx?case=2010-00204).
The Company has not quantified and tracked savings from the exchange of the
best practices.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 13
Responding Witness: Kent W. Blake
Q-13.

Refer to the response to AG-1-51. Are any costs charged to KU (1) during the
test period or (2) projected to be charged to KU during the forecast period by PPL
EU Services Corporation? If so, identify, quantify and explain the amounts of
such charges (1) during the test period or (2) projected to be charged to KU during
the forecast period by account.

A-13.

No.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 14
Responding Witness: Kent W. Blake / Counsel
Q-14.

Refer to the response to AG-1-51. Identify the "federal affiliate transaction
regulations" that are being referred to in the response.

A-14.

The federal affiliate transaction regulations referenced in response to AG-1-51
are the FERC accounting regulations applicable to centralized service companies
located at 18 C.F.R. §§ 366.1–369.1 (2017).

 Response to AG-2 Question No. 15
Page 1 of 2
Meiman
KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 15
Responding Witness: Gregory J. Meiman
Q-15.

Refer to the response to AG-1-54. For each of the following, show in detail how
the target amounts were developed and also show in detail how actual achieved
results were calculated:
a. LKE Net Income Target and Actual
b. LKE EBIT Target and Actual
c. Customer Satisfaction payout percentage
d. Electric Distribution Operations payout percentage
e. Payout percentage for each Plant
f. Information Technology payout percentage

A-15.
a. The LKE Net Income target was developed during the 2015 business planning
and budgeting process and reflects budgeted revenue less operating, interest
and income tax expenses. Actual net income results for 2015 were compared
to budget to determine the achievement. The budget for 2015 assumed a
payout based on 100% achievement of the target. See attachment being
provided in Excel format. For the forecasted year, the net income target is no
longer included as a measure.
b. For 2015, the EBIT incentive measure was not included in the calculation of
revenue requirement; however, the calculation is provided in the attachment
to the response to part a.
c. The Customer Satisfaction target of 18 points requires the company’s
customer satisfaction score to be above the peer group competitive range for
3 of the 4 quarters, earning six points per quarter.

 Response to AG-2 Question No. 15
Page 2 of 2
Meiman
In 2015 the company was above the peer group competitive range all 4
quarters, earning 24 points. In quarter 1 and quarter 3, the company earned
one point for ranking second within the peer group and in quarter 4, the
company earned two points for ranking first within the peer group.

d. The Electric Distribution Operations safety target was developed during the
2015 business planning process and is based on historical recordable
incidents, projected performance and industry trending. The OSHA formula
(# of recordable incidents x 200,000 / # of hours worked) is used to calculate
actual results which reflect incidents that require medical treatment beyond
first aid, days away from work, restricted work, transfer to another job, or loss
of consciousness. See attached.
The Electric Distribution Operations electric reliability measure was based on
a Customer Average Interruption Duration Index (CAIDI) which is the sum
of customer minutes interrupted divided by the total number of customers
whose service was interrupted. It is calculated by dividing SAIDI (System
Average Interruption Duration Index) by SAIFI (System Average
Interruption Frequency Index). The 2015 target was based on 2015 business
plan target values for SAIDI and SAIFI combined with historic CAIDI
performance. Electric Distribution’s 2015 actual CAIDI result of 92.21 was
calculated based on 2015 outage data in the Outage Management System. See
attachment being provided in Excel format.
e. The Plant budget and KPI targets were developed through the 2015 budget
and business planning processes, respectively. The fleet safety (recordable
incident rate) target is established and then allocated based on plant
headcount. Availability targets are established at the fleet level and then
allocated based on capacity. Targets are determined based on historical
performance. Actual results are compared to target to determine achievement
for each measure. See attachment being provided in Excel format.
f. Information Technology Telecommunications targets are based on historical
performance relative to safety, internal customer satisfaction, and average
team competency. Actual results are compared to target to determine
achievement for each measure. See attachment being provided in Excel
format.

 The attachments are
being provided in
separate files in Excel
format.

Response to AG-2 Question No. 16
Page 1 of 2
Meiman
KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 16
Responding Witness: Gregory J. Meiman
Q-16.

Refer to the response to AG-1-54. Refer to the 2015 Customer Satisfaction
Results Summary.
a. What does a 50 percent customer satisfaction measurement indicate?
b. Does a 50 percent customer satisfaction measurement indicate that half of the
customers are satisfied and the other half are not? If not, explain fully.
c. What does a 43 percent customer satisfaction measurement indicate?
d. What does a 66.6 percent customer satisfaction measurement indicate? Does
this mean that two-thirds of the customer are satisfied and one-third are not?
If not, explain fully.
e. Which companies are in the "Peer Average" for 2015 Customer Satisfaction?
f. How were the companies in the "Peer Average" selected?

A-16.
a. A 50 percent customer satisfaction measurement indicates that 50 percent of
customers surveyed rated their overall satisfaction with the company a 9 or
10 on a 10 point scale.
b. No. It means that the balance of customers (50 percent) surveyed rated their
overall satisfaction with the company an 8, 7, 6, 5, 4, 3, 2, or 1.
c. A 43 percent customer satisfaction measurement indicates that 43 percent of
customers surveyed rated their overall satisfaction with the company a 9 or
10 on a 10 point scale.
d. A 66.6 percent customer satisfaction measurement indicates that 66.6 percent
of customers surveyed rated their overall satisfaction with the company a 9 or
10 on a 10 point scale and 33.4% gave a rating of 8, 7, 6, 5, 4, 3, 2, or 1.

 Response to AG-2 Question No. 16
Page 2 of 2
Meiman
e. AEP Midwest, Duke Carolinas, Georgia Power, Duke Midwest,
MidAmerican, South Carolina Electric and Gas.
f. Peer utilities were selected based on characteristics similar to LG&E and KU.
• Type of services provided (Electric or Electric and Gas)
• Size of service area and number of customer’s served
• Performance in syndicated studies (e.g. top ranking in JD Power studies)
• Customer demographic profiles

 Response to AG-2 Question No. 17
Page 1 of 2
Meiman
KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 17
Responding Witness: Gregory J. Meiman
Q-17.

Refer to the response to AG-1-68.
a. How much of the $11.506 million Team Incentive Award was reflected as
expense by KU electric utility operations in the test year? Show the amounts
by account.
b. What is the comparable total amount of Team Incentive Award for the
forecasted period?
c. How much of the total forecasted period Team Incentive Award was reflected
as expense by KU electric utility operations in the forecasted period? Show
the amounts by account.
d. Identify each item and the related dollar amount that is included in the $1.8
million of Other Benefits.
e. How much of the $1.8 million Other Benefits were expensed by KU electric
utility operations in the test year? Show the amounts by account.
f. What is the comparable total amount of Other Benefits Expense for the
forecasted period? Show a breakout of KU electric utility operations and show
the amounts by account.
g. What calendar period are the "Test Year" amounts in the Attachment to the
response to AG-1-68 for?

A-17.
a. The $11.506 million Team Incentive Award shown in AG-1-68 is the total
company amount included in expense for KU electric utility operations for
the forecasted test period. See attachment for the amounts by account. The
Kentucky jurisdictional amount included in the forecasted test year is $10.42
million. See response to Kroger 2-3 for the details.

 Response to AG-2 Question No. 17
Page 2 of 2
Meiman
b. The amount shown in AG-1-68 for Team Incentive Award is for the total
company for the forecasted test period. See attachment to the response to
part a. As stated in response a, the Kentucky Jurisdictional amount is $10.42
million included in expense.
c. See the response to parts a. and b.
d. See attached for each item and the related dollar amount that is included in
the $1.8 million of Other Benefits.
e. The $1.8 million Other Benefits is the amount included in expensed by KU
electric utility operations in the forecasted test year. The expense amounts
are charged to FERC account 926.
f. The amount included in AG-1-68 for Other Benefits is for the forecasted test
period. See attachment to the response to part d.
g. "Test Year" amounts in the Attachment to the response to AG-1-68 for is the
Forecasted Test Year ending 6-30-18.

 Attachment to Response to AG-2 Question No. 17(a)
Page 1 of 2
Meiman
Kentucky Utilities Company
Case No. 2016-00370
Construction-Other
107
108
163
184
426
512
908
Total Construction-Other
Operating
500
501
502
505
506
510
511
512
513
514
541
542
546
551
553
554
556
560
561
562
566
570
571
580
581
582
583
584
586
587
588

Total
2,435,235
103,496
157,070
976,269
42,755
57,862
89,005
3,861,692
Total
675,798
229,157
748,037
466,584
125,197
594,275
92,214
552,109
124,110
24,243
12,882
3,650
26,959
9,705
67,506
2,767
200,329
234,471
323,853
37,146
10,323
88,899
9,082
110,542
34,498
60,397
191,016
454,173
268,452

 Attachment to Response to AG-2 Question No. 17(a)
Page 2 of 2
Meiman

Operating
590
592
593
594
595
598
901
902
903
907
908
920
935
Total Operating

Total
43,127
461,407
30,798
3,836
318,088
59,057
1,125,367
57,922
25,509
3,556,333
45,857
11,505,675

Total TIA

15,367,367

 Attachment to Response to AG-2 Question No. 17(d)
Page 1 of 1
Meiman
Kentucky Utilities Company
Case No. 2016-00370

Other Benefits by Component

PBGC Premium
Wellness Programs
Consulting, primarily Actuarial Services
Administrative fees and Other miscellaneous benefits
Medical Fees (ACA)
Family Assistance Program
Total

Total
Expensed to
FERC 926
516,372
482,322
421,311
195,771
177,421
40,663
1,833,860

 Response to AG-2 Question No. 18
Page 1 of 2
Arbough
KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 18
Responding Witness: Daniel K. Arbough
Q-18.

Workers Compensation. Refer to the response to AG-1-69.
a. Referring to the $619,974 of forecasted WC cost in the test year, identify the
comparable total amount of forecasted WC cost for the 12 month period
ending February 28, 2017.
b. The response to AG-1-69 (b) indicates that the policy premium for 12/31/1512/30/16 was $449,660. An invoice was attached to the response showing a
premium of $461,748 for the policy term of 12/31/2016 - 12/31/2017. The
response to AG-1-69 (b) states that "KU estimated a 1% increase in that
premium for 2017 and a 5% increase for 2018." Does the Company agree that
the comparison of the 2017 premium of $461,748 with the 2016 premium of
$449,660 indicates a 2.7% increase? If not, explain fully why not.
c. Show in detail how the 1% 2017 increase and 5% 2018 estimated increases
were derived.

A-18.
a. KU’s forecasted workers’ compensation cost for the 12 month period ending
February 28, 2017 is $434,980, which includes 11 months of actual costs and
1 month of forecasted costs.
b. The premium for the 12/31/15-12/31/16 policy period was $449,660 and was
allocated between KU and LG&E as described in KU’s response to Question
1-69a. The policy for the 12/31/16-12/31/17 had not been renewed at the time
the forecast upon which the 7/1/17-6/30/18 Test Year was prepared.
Therefore, KU estimated a 1% increase in that premium for 2017 and included
that cost in the 7/1/17-6/30/18 Test Year. Subsequently, the policy for the
12/31/16-12/31/17 period was renewed for $461,748, which does represent a
2.7% increase.
c. KU estimated the percentage increase in workers’ compensation insurance
premiums based upon salary escalation rates in place at the time the forecast

 Response to AG-2 Question No. 18
Page 2 of 2
Arbough
was prepared and market input from its external insurance broker. See
calculation below of total premium escalation factors for 2017 and 2018.

Market Premium per Broker
Preliminary Salary Escalation Rate
Total
Rounded Total

2017
0.00%
1.30%
1.30%

2018
2.00%
2.86%
4.86%

1.00%

5.00%

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 19
Responding Witness: Daniel K. Arbough
Q-19.

Workers Compensation. Refer to the response to AG-1-72. Why does the cost for
Workers Comp decrease from $1,190,019 in 2015 to $507,946 in 2016?

A-19.

The decrease in KU’s workers’ compensation cost between 2015 and 2016 is
primarily due to the change in the reserve. The reserve is calculated by an outside
consultant and is based on estimated future charges for claims incurred.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 20
Responding Witness: Valerie L. Scott
Q-20. Refer to the response to AG-1-72. Identify and provide the journal entries that
resulted in the $926,795 credit for FASB 112 costs in December 2015 and the
$56,608 debit to FASB 112 costs in December 2016.
A-20. The FAS 112 (post-employment) is included in the labor burden process as
explained in AG 1-228. On an annual basis, the company meets with Willis Towers
Watson actuaries (Towers) and agrees with assumptions to use in the
calculation. The actuaries estimate the cost. This estimate is used to develop the
FAS 112 burden rate for budgets and actual data. The rate is updated at year-end
when Towers calculates the actual liability. The difference in the balance of the
liability account on the general ledger and the actual year-end liability from Towers
is included in the system burden process during the year-end close. This process
reverses the post-employment that had been initially calculated in December and
records the amount necessary to balance to the actual liability. The amounts are
recorded to capital (FERC Account 107), expense (FERC Account 926), or any
other balance sheet account (see AG 2-6 for a list of these other accounts) based on
straight time labor charges. The impact of the system burdening processes results
in system generated “journal entries” that had the following impact on the FASB
112 costs.
2015

2016

December post-employment burden
calculated from Towers estimate

$ 20,295

$ 14,634

Reversal of December postemployment burden calculated from
Towers estimate

(20,295)

(14,634)

Post-employment burden calculation
based on Towers actual liability

(926,783)

56,622

(12)
$ (926,795)

(14)
$ 56,608

True-up clearing entries

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 21
Responding Witness: Valerie L. Scott
Q-21.

Refer to the response to AG-1-72. Identify, quantify and explain each type of
Other Benefit that is included in the $1.351 million for 2015 and $1.135 million
for 2016.

A-21.
FSA forfeitures (a)
Affordable Care Act Fees (b)
Family Assistance Program
Fidelity Fees
Legal Services
Retiree Medical and Retiree Life
Administration Fees
Pension Benefit Guaranty Corporation
Premium (c)
Pension Valuation
Smoking Cessation
Actuarial Fees
Wellness Initiatives
Total

2015
$ (239,095.91)

332.46
253,241.62

2016
$ (329,297.92)
222,488.79
42,932.36
14,502.89
237.99
224,751.18

271,781.36

-

424.64
48,750.98
428,248.33
544,719.69
$1,351,159.50

957.86
51,710.43
279,238.73
627,169.48
$1,134,691.79

-

42,756.33
-

(a) Flexible Spending Account forfeitures
(b) Affordable Care Act fees were applied to labor burdens starting in 2016
(c) Pension Benefit Guaranty Corporation Premium in 2016 was paid directly
from the pension plan rather than charged to burdens

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 22
Responding Witness: Daniel K. Arbough
Q-22.

Refer to the response to AG-1-81. Have any expenses for lawsuit judgment and/or
settlements been included in the Forecasted Test Year? If not, explain fully why
not. If so, identify the amounts included and explain fully how they were derived.

A-22.

There are no lawsuit judgments and/or settlements included in the Forecasted Test
Year. The Company had no basis on which to estimate if there would be lawsuit
settlements or how much they might be.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 23
Responding Witness: Valerie L. Scott
Q-23.

Refer to the response to AG-1-84.
a. Provide a breakout of the 2016 and 2015 Bad Debt Write-Offs amounts by
rate class.
b. Provide a breakout of the 2016 and 2015 Collection of Written-Off Accounts
amounts by rate class.

A-23.

KU does not record bad debt write-offs or collection of written-off accounts by
rate class (code). The Company does track this activity by customer class, which
is provided below:
2015
Collections
Bad Debt
of WrittenWrite-offs
off Accounts
(a)
(b)

Customer
Class
Residential
Customers
Commercial
Customers
Industrial
Customers
Public
Authorities
Customers
Street Lights
Customers
Total

$ 4,944,334

$

406,896

$

469,200

$

$

169,668

$

-

$
7,625
$ 5,590,827

2016
Collections
Bad Debt
of WrittenWrite-offs
off Accounts
(a)
(b)
$ 3,839,701

$

455,295

20,971

$

389,698

$

31,711

$

42,548

$

880,071

$

659,185

$

-

$

8,577

$

379

$
$

469
470,884

$
3,977
$ 5,122,024

$
1,802
$ 1,148,372

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 24
Responding Witness: Daniel K. Arbough
Q-24.

Refer to the response to AG-1-89. Are the amounts in the "Test" column for the
forecast period 7/1/2017 through 6/30/2018? If not, provide comparable amounts
for the forecast period 7/1/2017 through 6/30/2018.

A-24.

The Company confirms that the amounts in the “test” column are for the forecast
period 7/1/2017 through 6/30/2018.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 25
Responding Witness: John P. Malloy
Q-25.

Refer to the response to AG-1-102.
a. As of December 31, 2016, how many AMI meters were deployed and what
was the cost of those AMI meters?
b. What is the average service life of each type of meters that the Company had
installed as of December 31, 2016?
c. What is the average cost of the AMI meters that the Company proposes to
install?

A-25.
a. KU deployed 1,669 AMS meters as of December 31, 2016 at a cost of
$241,059.
b. Service life shown below is the amount of time from initial meter installation
through Feb. 2017.
Type of Meter
Single-Phase
Three-Phase

Average Service Life
26
12

c. See Section 5.3 on page 11 of Exhibit JPM-1 of John Malloy’s testimony
($104.09 for electric meter on average and $74.09 for gas index).

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 26
Responding Witness: Daniel K. Arbough
Q-26.

Refer to the response to AG-1-108.
a. Show in detail how the Real Risk-Free Return of -0.71% was derived.
b. Show in detail how the Equity Risk Premium of 6.0% was derived.
c. Is the 8.96% the projected return for common stock equity investments? If
not, explain fully.

A-26.
a. The Real-Risk Free is derived by comparing the 1-yr Treasury less current
inflation year-over-year (Core CPI). As of end of year 2015 that was 60 bps
minus 1.31% published by Bloomberg. See pages 1 and 2 of attached.
b. Various sources are considered when deriving the Equity Risk Premium
including capital market assumptions used by our Pension Advisor and
different publications such as Ibbotson SBBI Classic Yearbook. See page 3
of attached.
c. The 8.96% represents the expected return of growth-seeking assets of the
portfolio, including US and Non-US Equity, Alternative Investments, such as
hedge funds & private equity, and certain types of Fixed Income, such as
High-Yield and Emerging Market Debt (hard and local currency).

 ,------

Attachment to Response to AG-2 Question No. 26
Page 1 of 3
Arbough

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Page 2 of 3
Arbough

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 Attachment to Response to AG-2 Question No. 26
Page 3 of 3
Arbough
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· Table 11-4 illustrates the equity risk p~miuti\ calculation
using several different market indices and the income
return on three government bonds of different horizons.
0

Tabla 1l·4: Equity Risk Premium with Differlint Mmet Indices

fs~i~t~~.~.~~.. --.--..............................
lnremicdlate·
Horizon !'hi

Long·

Horlltlll ('M

Shcn-

~amii:i_

l"'J

.~~f..~~ ....................._.._............~:!!~....-- . -·.-·?.:5.L...-........~:P.L.
Total Value-Weighted NYSf

6.76

7.32

a.31

N·vsE.'iie;ii65·1::_2....-...-·- ..- .....6::23"..................659..................7:7.ii""-·
Outa Imm 1S'l&-2013.

TI1e equity risk premium is calculated by subtracting the
arithmetic mean of the government bond income return
from the arithmetic mean of the stock mar1<et to~I return.
Table 11-5 demonstrates this calculation for the long·"·
horizon equity risk premium.
Table 11-5: Long-Horiron tquity Hlsk Premium Galculatlon
Arlthmeljc Mean

~~t·T~i'"'"'"jij'.;f:j:i;
lm,rfiml!lln

S&P 500

. Rl11!Jm\'llo)

12.05

-

Equity Risk

Rete('r;J .~ ~~c~l
5.09 = 6.96

~~~~Y~t~~~~l@~:::::~~:~~~~~F:::~~:: :::~~~~~:~:~::~~~~:::
Oala from 1928-201:!.

Data for the New York Stock Exchange is obtained from
Morningstar and the Centerfor.Resmm:h in Security Prices
(CRSP) at the University of Chicago's Graduate School of
Business. The "Total" series .is a capitalization-weighted
index and includes all stocks traded on the New York Stock
Exchange except closed-end mutual funds, real estate
investment trusts, foreign stocks, ~nd Americus Trusts.
Capitalization-weighted means that the weight of each
stock in the index, for a given month, is proportionate to
its market capitalization (price times number of shares
outstanding) at the beginning of tf1at month. The "Decile
1-2" series includes all stocks with capitalizations that
rank within the upper 20 percent of companies traded on
the New York Stock Exchange, and it is therefore a largecepttalization index. For more information on the Center
for Research in Security Pricing. data methodology, see
Chapter.7

152

The Market Beoohmork ~nd Finn Size
Although not restricted to include only the 500 largest companies, the S&P 5oo is considered a large campany index.
The returns of the S&P 500 are capitalization weighted,
which means that the weight of each stock in the index, for
a given month, is proportionate to its market capitalization
(price times number of sh~res outstanding) at1he beginning
of that month. The larger companies ln the index therefore
receive the majority of the weight The use of the NYSE
"Deciles 1-2" series results in an even purer large company
index. However, if using a large stock index to calculate
the equity risk premium, an adjustment is usually needed
to account for the different risk and rerurn characteristics
of small stocks. This was discussed further in Chapter 7 011 ·
the size premium.
The Risk-Free Asset
The equity risk premium can ba calculated for a. variety of
time horizons when given the choice of risk-free asset to
be used in the calculation. Chapter 3 provides equity risk
premia calculations fo( short-, intermediate-, and long-term
horizons. The short-, intennediate-, and long-horizon equity
risk premia are calculated using the income retum from a
30-day Treasury bill, a 5-year Treasllry bond, and a 20-ysar
Treasury bond, respectively.
20-Year versus 30-Vaar Treasuries
Our methodology for estimating 1he long-horizon equity
risk premium makes use of the income return on a 20-year
Treasury bond; however, the Traasury currently does not
issue a 20..year bond. The 30-year bond that the Treasury
recently began issuing again is theoretically morn correct
when dealing with to the long-term nature of business
valuation, yet Ibbotson Associates instead creates a series
of returns using bonds on the market with approximately 20
years to maturity. The reason for the use of a 20-year maturity bond is that 30-year Treasury securities have o'nly been
issued over the relatively recent past. starting in February
of 1977, and were not issued at all through the early 2000s.

The same reason exists for why we do not use the 1G-year
Treasury bond-a long history of market data is not available for 10-year bonds. We have persisted in using a 20-year
bond to kaep the basis of the tim·e series ctlnsistent.

 Response to AG-2 Question No. 27
Page 1 of 2
Meiman
KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 27
Responding Witness: Gregory J. Meiman
CONFIDENTIAL INFORMATION REDACTED
Q-27.

Refer to the response to AG-1-67.
a. How has the Company estimated the impact of work force turnover for the
Forecasted Test Year ending June 30, 2018? Identify, quantify and explain
how the impact of work force turnover has been incorporated.
b. Of the 198 positions listed in the response to AG-1-67 where turnover
occurred and a replacement was hired, does the Company agree that the
annual salaries of the replacement employee are typically [BEGIN
CONFIDENTIAL]
[END CONFIDENTIAL] than the annual salary of
the employee who has been replaced? If not, explain fully why not.
c. Are the replacements listed in the response to AG-1-67 representative of
normal experience where positions are vacated and are replaced, on average,
with new employees at lower salary levels? If not, explain fully why not.
d. Are the average salaries of the replacement employees approximately
[BEGIN CONFIDENTIAL] [END CONFIDENTIAL] than the salaries of
the employees that have been replaced? If not, what is the relationship of (1)
the salaries of the replacement employees and (2) the salaries of the
employees who were replaced?

A-27.
a. Retirements and other forms of turnover that have taken place in the previous
12 months, as well as new hires that have taken place in the previous 12
months, are factored into average wage rates that are pulled from the
Company’s PeopleSoft system. This is described in more detail in the filed
testimony of Daniel K. Arbough on pages 5 and 6.
b. Of the 198 positions replaced for the calendar years information provided in
AG 1-67, 139 were replaced by employees with xxxxx salaries, 31 were
replaced by employees with xxxxxx salaries, and 28 were the xxxx. The

 Response to AG-2 Question No. 27
Page 2 of 2
Meiman
company evaluates how each position should be replaced based on the needs
of the business and replaces those employees at the current market rate. The
redacted information requested is confidential and is being provided under
seal pursuant to a petition for confidential protection.
c. The average salaries of those employees that were replaced during the
calendar years presented in AG 1-67 were xxxxxxxx; however, as a total
percentage of employees replaced, it was xxxxxxxx. As stated above in
response to part a, after the evaluation of how each position should be
replaced, a new employee is hired based on current market rates. The
redacted information requested is confidential and is being provided under
seal pursuant to a petition for confidential protection.
d. See response to part c.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 28
Responding Witness: Christopher M. Garrett
Q-28.

Refer to the response to AG-1-134.
a. [BEGIN CONFIDENTIAL]
[END CONFIDENTIAL]
b. Was any book gain or loss recorded on the assets identified in response to part
a? If not, explain fully why not. If so, identify the related book gain or loss.
c. Explain how the Company has treated (1) the tax gain or loss and (2) the book
gain or loss on disposal of assets.

A-28.
a. See attached. The information requested is confidential and is being provided
under seal pursuant to a petition for confidential protection.
b. The Company recorded a book gain of $47,301 on the sale of vehicles and
land in 2015. No other book gain or loss was recorded on other assets. Code
of Federal Regulations 18 CFR, Chapter 1, Subchapter C, Part 101 (FERC
USofA) Plant Instruction No. 5, Electric Plant Purchased or Sold requires a
gain or loss to be recorded when an operating system is sold or purchased.
The remaining assets identified in response to part a. were retired, not
sold. Since the transaction involved a retirement only, KU followed the
guidelines prescribed in the FERC USofA, Plant Instruction 10 - Additions
and Retirements of Electric Plant. Assets are depreciated using group
depreciation. Under group depreciation, lives for individual assets are not
maintained, rather all assets are depreciated using a composite, or group, rate
for all the assets within the group. No gain or loss is recorded when using
group depreciation unless it meets the guidelines of an operating system.
c. The Company recognizes a deferred tax asset or liability for the difference in
book and tax gains and losses.

 The entire attachment is
Confidential and
provided separately
under seal.

KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 29
Responding Witness: Christopher M. Garrett
Q-29.

Refer to the response to AG-1-135. Please explain whether any accelerated tax
depreciation including bonus tax depreciation is allowed for Kentucky
corporation income tax purposes. Explain the limitations on tax depreciation for
Kentucky corporation income tax purposes and how those were applied in the
Part III - Taxable Income Computation.

A-29.

For income tax purposes, Kentucky does allow accelerated tax depreciation using
the MACRS depreciation method in accordance with the Internal Revenue Code.
Kentucky does not conform to the federal treatment of bonus tax depreciation and
requires an addition to federal taxable income for any bonus tax depreciation
taken at the federal level.
In Part III – Taxable Income Computation of the Kentucky Corporate Income Tax
Return, line 4 Depreciation adjustment is adding back the federal tax depreciation
deduction taken including bonus tax depreciation to federal taxable income. The
line 15 Depreciation adjustment is subtracting Kentucky state tax depreciation
not including bonus tax depreciation to federal taxable income. The result is
bonus tax depreciation is not deducted for Kentucky corporation income tax
purposes.

 Response to AG-2 Question No. 30
Page 1 of 2
Garrett
KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 30
Responding Witness: Christopher M. Garrett
Q-30.

Refer to the response to AG-1-136(a). Refer to the Deferred Income Tax Expense
for the 12 ME 6/30/18, Federal Timing Differences.
a. Show in detail how the $6.180 million Storm Damages amount was derived.
b. Show in detail how the $5.323 million Muni True-Up Regulatory Liability
amount is derived
c. Show in detail how the $10,889 Off System Sales Tracker amount was
derived.
d. Show in detail how the $32.225 million ARO CCR amount was derived.
e. What are the non-deductible pensions?
f. Show in detail how the $2.835 million for non-deductible pensions was
derived.
g. Show in detail how the $30 million for Repair Allowance was derived.
h. Show in detail how the $48.183 million Federal NOL Utilization was derived.

A-30.
a. See attached.
b. See attached.
c. See attached.
d. See attached.
e. Contributions paid in connection with a qualified pension plan are deductible
for income tax purposes, pensions expensed for the financial statements are
nondeductible for income tax purposes.

 Response to AG-2 Question No. 30
Page 2 of 2
Garrett

f. See attached.
g. See response to Question No. 5.
h. See attachment to response to AG 1-134.

 Kentucky Utilities Company
Case No. 2016-00370
Timing Differences - Detail
($ dollars)

12/31/2016

Balances
12/31/2017

12/31/2018

a. Storm Damages:
2008 Wind Storm
2009 Ice Storm
Virginia Mountain Storm
Total Storm Damages

786,727
20,509,839
472,826
21,769,392

567,175
14,786,163
0
15,353,338

b. Municipal Generation True-up

9,952,324

2,721,099

c. Off System Sales Tracker

(29,361)

(32,204)

347,623
9,062,487
0
9,410,111

109,776
2,861,838
236,413
3,208,027

109,776
2,861,837
2,971,613

219,552
5,723,675
236,413
6,179,640

(694,465)

3,615,613

1,707,782

5,323,395

(51,139)

1,421

9,468

10,889

Activity
d. Coal Combustion Residuals AROs
Deduct Pond Closure Spend
Addback Amortization
Total Coal Combustion Residuals AROs
f. Pensions
Deduct Pension Contributions
Addback Pension Expense
Total Pensions

2017
(17,491,920)
962,769
(16,529,152)
2017
(11,868,792)
8,795,937
(3,072,855)

Addback Activity/Amortization
1/2 Year 2017
1/2 Year 2018
Forward Year

2018
(51,419,038)
3,497,958
(47,921,080)
2018
(10,557,934)
7,960,618
(2,597,316)

Deduct Payments/Addback Expense
1/2 Year 2017
1/2 Year 2018
Forward Year
(8,745,960)
(25,709,519)
(34,455,479)
481,384
1,748,979
2,230,364
(8,264,576)
(23,960,540)
(32,225,116)
1/2 Year 2017
(5,934,396)
4,397,969
(1,536,427)

1/2 Year 2018
(5,278,967)
3,980,309
(1,298,658)

Forward Year
(11,213,363)
8,378,278
(2,835,085)

Attachment to Response to KU AG-2 Question No. 30(a-d,f)
Page 1 of 1
Garrett

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 31
Responding Witness: Christopher M. Garrett
Q-31.

Refer to the response to AG-1-142.
a. Has the Company included any deferred tax asset related to NOL
carryforwards or contribution carryforwards in rate base for the Forecasted
Test Year?
b. If the answer to part a is "yes" identify the amount, and provide a breakout of
the Forecasted Test Year deferred tax asset amount between (1) net operating
loss carryforward and (2) contribution carryforwards.

A-31.
a. Yes, the Company has included deferred tax assets related to NOL
carryforwards and contribution carryforwards in rate base for the Forecasted
Test Year.
b. See attachment to response to AG 1-36.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 32
Responding Witness: Christopher M. Garrett
Q-32.

Refer to the response to AG-1-145. Provide a break out of the anticipated property
tax increase in account 408.1 from the $26.867 million for 2016 to the $29.910
million for the Forecasted Test Year between (1) changes in the property tax rates,
(2) changes due to increased plant and (3) other (explain any other factors
associated with the projected property tax expense increase).

A-32.

See attachment to response to KIUC 1-25.

 Response to AG-2 Question No. 33
Page 1 of 2
Spanos
KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 33
Responding Witness: John J. Spanos
Q-33.

Refer to the response to AG-1-181.
a. Identify and provide a copy of all support relied upon for the 2.5% inflation
factor used for terminal net salvage projections.
b. How much lower would the terminal net salvage component of depreciation
rates be if a 2.0% inflation factor were used?
c. Provide supporting calculations for the response to part b.
d. For each plant asset for which terminal net salvage was computed, show in
detail exactly how the 2.5% inflation factor was applied to the dismantlement
estimates and clearly identify the period during which the 2.5% annual
inflation factor was applied.
e. Provide calculations for part (d) showing exactly how the 2.5% inflation
factor was applied, for how many years it was applied, and the starting
balance of dismantlement cost estimate for each plant asset to which it was
applied.

A-33.
a. The 2.5% escalation factor is supported by the Consumer Price Index for the
last 30 years.
b. The attached schedule sets forth the depreciation rates for generation accounts
when using a 2.0% escalation factor. The depreciation expense is reduced by
$5,869,967 from that set forth in exhibit JJS-KU-1.
c. The attached depreciation calculation sets forth the results from part b.
d. The terminal net salvage is applied at the location level as shown by the
schedule on pages VIII-2 and VIII-3 of Exhibit JJS-KU-1. The 2.5%
escalation factor is calculated up to the date of retirement.

 Response to AG-2 Question No. 33
Page 2 of 2
Spanos

e. See the attached schedule, which is the workpaper for the terminal net
salvage.

 KENTUCKY UTILITIES

TABLE 1. SUMMARY OF ESTIMATED SURVIVOR CURVES, NET SALVAGE PERCENT, ORIGINAL COST, BOOK DEPRECIATION RESERVE AND
CALCULATED ANNUAL DEPRECIATION ACCRUAL RATES AS OF DECEMBER 31, 2015

ACCOUNT
(1)

NET
SALVAGE
PERCENT
(3)

SURVIVOR
CURVE
(2)

ORIGINAL
COST
(4)

BOOK
DEPRECIATION
RESERVE
(5)

CALCULATED ANNUAL
ACCRUAL
ACCRUAL
AMOUNT
RATE
(7)
(8)=(7)/(4)

FUTURE
ACCRUALS
(6)

COMPOSITE
REMAINING
LIFE
(9)=(6)/(7)

DEPRECIABLE PLANT
INTANGIBLE PLANT
302.00
303.00
303.10

FRANCHISES AND CONSENTS
MISCELLANEOUS INTANGIBLE PLANT
CCS SOFTWARE

20-SQ
5-SQ
SQUARE

*

0
0
0

TOTAL INTANGIBLE PLANT

55,918.83
51,209,431.96
41,045,494.53

52,578
17,788,070
26,586,875

3,341
33,421,362
14,458,620

2,029
10,731,787
4,131,034

3.63
20.96
10.06

1.6
3.1
3.5

92,310,845.32

44,427,523

47,883,323

14,864,850

95,533,749.13
5,556,451.46
1,102,956.39
4,690,069.46
2,297,196.43
22,711,518.61
45,507,722.44
8,397,192.12
19,505,041.37
16,258,655.69
51,066,601.71
33,248,360.76
15,817,337.72

23,445,099
3,082,793
713,561
4,858,759
2,008,651
14,083,124
8,775,718
7,331,103
18,115,555
14,507,970
32,981,268
15,639,157
13,742,096

82,597,363
3,084,868
400,425
65,814
403,405
9,763,971
39,007,391
1,653,893
2,754,839
2,888,792
21,659,996
19,936,589
3,182,455

1,714,867
65,944
16,627
8,799
30,046
507,382
2,015,885
90,620
150,144
160,168
1,026,693
902,154
174,668

1.80
1.19
1.51
0.19
1.31
2.23
4.43
1.08
0.77
0.99
2.01
2.71
1.10

48.2
46.8
24.1
7.5
13.4
19.2
19.4
18.3
18.3
18.0
21.1
22.1
18.2

321,692,853.29

159,284,854

187,399,801

6,863,997

2.13

27.3

4,562,600.30
39,480.55
322,828.55

2,148,119
34,420
304,586

2,414,481
5,061
18,243

48,425
274
986

1.06
0.69
0.31

49.9
18.5
18.5

4,924,909.40

2,487,125

2,437,785

49,685

1.01

49.1

1,692,976.56
583,381.44
2,549,285.01
4,560,022.06
1,558,538.26
37,239.96

1,862,274
641,720
2,804,214
5,016,024
1,714,392
40,964

0
0
0
0
0
0

0
0
0
0
0
0

-

-

10,981,443.29

12,079,588

0

0

-

-

531,933,576.48
73,021,689.57
40,216,199.41
41,452,992.23
335,039,815.44
334,559,939.62
138,832,539.39
347,267,291.09
269,565,973.05
425,512,609.68
735,664,440.23
66,258,293.73
118,460,532.34
253,701,662.20

92,306,117
18,602,423
22,985,071
15,937,592
74,041,334
77,676,980
47,058,422
96,144,803
67,704,359
168,531,725
135,118,842
59,902,017
31,824,024
77,381,453

498,140,153
62,451,652
19,241,938
27,588,050
277,750,472
273,610,957
101,492,395
275,431,198
220,731,232
286,766,767
652,042,109
10,994,357
94,928,746
194,079,326

11,124,720
1,404,511
2,602,922
2,105,633
14,672,211
14,360,256
5,617,564
15,302,639
12,275,159
13,903,449
30,032,084
613,758
4,568,202
8,878,216

2.09
1.92
6.47
5.08
4.38
4.29
4.05
4.41
4.55
3.27
4.08
0.93
3.86
3.50

44.8
44.5
7.4
13.1
18.9
19.1
18.1
18.0
18.0
20.6
21.7
17.9
20.8
21.9

3,711,487,554.46

985,215,162

2,995,249,352

137,461,324

3.70

21.8

STEAM PRODUCTION PLANT
311.00

STRUCTURES AND IMPROVEMENTS
TRIMBLE COUNTY UNIT 2
TRIMBLE COUNTY UNIT 2 SCRUBBER
SYSTEM LABORATORY
BROWN UNIT 1
BROWN UNIT 2
BROWN UNIT 3
BROWN UNIT 1, 2 AND 3 SCRUBBER
GHENT UNIT 1 SCRUBBER
GHENT UNIT 1
GHENT UNIT 2
GHENT UNIT 3
GHENT UNIT 4
GHENT UNIT 2 SCRUBBER

100-R2.5
100-R2.5
100-R2.5
100-R2.5
100-R2.5
100-R2.5
100-R2.5
100-R2.5
100-R2.5
100-R2.5
100-R2.5
100-R2.5
100-R2.5

*
*
*
*
*
*
*
*
*
*
*
*
*

(11)
(11)
(1)
(5)
(5)
(5)
(5)
(7)
(7)
(7)
(7)
(7)
(7)

TOTAL ACCOUNT 311 - STRUCTURES AND IMPROVEMENTS

311.10

STRUCTURES AND IMPROVEMENTS - ASH PONDS
TRIMBLE COUNTY UNIT 2 ASH POND
GHENT UNIT 1 SCRUBBER ASH POND
GHENT UNIT 1 ASH POND

100-S4
100-S4
100-S4

*
*
*

0
0
0

TOTAL ACCOUNT 311.1 - STRUCTURES AND IMPROVEMENTS - ASH PONDS
311.20

STRUCTURES AND IMPROVEMENTS - RETIRED PLANT
TYRONE UNIT 3
TYRONE UNITS 1 AND 2
GREEN RIVER UNIT 3
GREEN RIVER UNIT 4
GREEN RIVER UNITS 1 AND 2
PINEVILLE UNIT 3

100-R2.5
100-R2.5
100-R2.5
100-R2.5
100-R2.5
100-R2.5

*
*
*
*
*
*

(10)
(10)
(10)
(10)
(10)
(10)

TOTAL ACCOUNT 311.2 - STRUCTURES AND IMPROVEMENTS - RETIRED PLANT
312.00

BOILER PLANT EQUIPMENT
TRIMBLE COUNTY UNIT 2
TRIMBLE COUNTY UNIT 2 SCRUBBER
BROWN UNIT 1
BROWN UNIT 2
BROWN UNIT 3
BROWN UNIT 1, 2 AND 3 SCRUBBER
GHENT UNIT 1 SCRUBBER
GHENT UNIT 1
GHENT UNIT 2
GHENT UNIT 3
GHENT UNIT 4
GHENT UNIT 2 SCRUBBER
GHENT UNIT 3 SCRUBBER
GHENT UNIT 4 SCRUBBER
TOTAL ACCOUNT 312 - BOILER PLANT EQUIPMENT

65-R2
65-R2
65-R2
65-R2
65-R2
65-R2
65-R2
65-R2
65-R2
65-R2
65-R2
65-R2
65-R2
65-R2

*
*
*
*
*
*
*
*
*
*
*
*
*
*

(11)
(11)
(5)
(5)
(5)
(5)
(7)
(7)
(7)
(7)
(7)
(7)
(7)
(7)

Attachment to Response to AG-2 Question No. 33(b)
Page 1 of 7
Spanos

 KENTUCKY UTILITIES

TABLE 1. SUMMARY OF ESTIMATED SURVIVOR CURVES, NET SALVAGE PERCENT, ORIGINAL COST, BOOK DEPRECIATION RESERVE AND
CALCULATED ANNUAL DEPRECIATION ACCRUAL RATES AS OF DECEMBER 31, 2015

ACCOUNT
(1)
312.10

BOILER PLANT EQUIPMENT - ASH PONDS
TRIMBLE COUNTY UNIT 2 ASH POND
BROWN UNIT 1 ASH POND
BROWN UNIT 2 ASH POND
BROWN UNIT 3 ASH POND
GHENT UNIT 1 ASH POND
GHENT UNIT 4 ASH POND
GHENT UNIT 2 SCRUBBER ASH POND
TYRONE UNIT 3 - ASH POND
GREEN RIVER UNIT 3 - ASH POND
PINEVILLE UNIT 3 - ASH POND

NET
SALVAGE
PERCENT
(3)

SURVIVOR
CURVE
(2)

100-S4
100-S4
100-S4
100-S4
100-S4
100-S4
100-S4
100-S4
100-S4
100-S4

*
*
*
*
*
*
*
*
*
*

0
0
0
0
0
0
0
0
0
0

TOTAL ACCOUNT 312.1 - BOILER PLANT EQUIPMENT - ASH PONDS
312.20

BOILER PLANT EQUIPMENT - RETIRED PLANT
TYRONE UNIT 3
TYRONE UNITS 1 AND 2
GREEN RIVER UNIT 3
GREEN RIVER UNIT 4
GREEN RIVER UNITS 1 AND 2
PINEVILLE UNIT 3

65-R2
65-R2
65-R2
65-R2
65-R2
65-R2

*
*
*
*
*
*

(10)
(10)
(10)
(10)
(10)
(10)

TOTAL ACCOUNT 312.2 - BOILER PLANT EQUIPMENT - RETIRED PLANT AND ASH PONDS
314.00

TURBOGENERATOR UNITS
TRIMBLE COUNTY UNIT 2
BROWN UNIT 1
BROWN UNIT 2
BROWN UNIT 3
GHENT UNIT 1
GHENT UNIT 2
GHENT UNIT 3
GHENT UNIT 4

60-R2
60-R2
60-R2
60-R2
60-R2
60-R2
60-R2
60-R2

*
*
*
*
*
*
*
*

(11)
(5)
(5)
(5)
(7)
(7)
(7)
(7)

TOTAL ACCOUNT 314 - TURBOGENERATOR UNITS
314.10

315.00

BOOK
DEPRECIATION
RESERVE
(5)

3,934,563
0
0
0
1,700,699
652,598
13,775,965
313,507
19,354,161
0

77,928
0
0
0
226,760
48,341
706,460
16,983
860,185
0

1.69
2.44
1.24
3.57
0.96
2.63
-

50.5
7.5
13.5
19.5
18.5
22.5
-

76,491,074.19

36,759,581

39,731,493

1,936,657

2.53

20.5

91,162.48
35,937.44
41,300.90
599,315.53
152,243.76
145,202.53

100,279
39,531
45,431
659,247
167,468
159,723

0
0
0
0
0
0

0
0
0
0
0
0

-

-

1,065,162.64

1,171,679

0

0

-

-

89,907,009.94
8,340,751.67
13,741,664.70
45,458,100.43
38,748,250.59
31,826,255.72
43,067,738.16
57,957,357.43

20,271,673
3,801,260
9,070,939
20,614,566
20,826,042
21,384,390
29,423,726
33,064,819

79,525,108
4,956,529
5,357,809
27,116,439
20,634,586
12,669,704
16,658,754
28,949,553

1,833,970
679,299
407,878
1,445,537
1,173,145
744,559
849,375
1,408,391

2.04
8.14
2.97
3.18
3.03
2.34
1.97
2.43

43.4
7.3
13.1
18.8
17.6
17.0
19.6
20.6

329,047,128.64

158,457,415

195,868,482

8,542,154

2.60

22.9

TOTAL ACCOUNT 314.1 - TURBOGENERATOR UNITS - RETIRED PLANT

3,433,226

70-R3
70-R3
70-R3
70-R3
70-R3
70-R3
70-R3
70-R3
70-R3
70-R3
70-R3
70-R3
70-R3
70-R3

*
*
*
*
*
*
*
*
*
*
*
*
*
*

(11)
(11)
(5)
(5)
(5)
(5)
(7)
(7)
(7)
(7)
(7)
(7)
(7)
(7)

ACCESSORY ELECTRIC EQUIPMENT - RETIRED PLANT
TYRONE UNIT 3
GREEN RIVER UNIT 3
GREEN RIVER UNIT 4
TOTAL ACCOUNT 315.1 - ACCESSORY ELECTRIC EQUIPMENT - RETIRED PLANT

70-R3
70-R3
70-R3

*
*
*

(10)
(10)
(10)

COMPOSITE
REMAINING
LIFE
(9)=(6)/(7)

676,102
575,456
1,831,841
91,266
7,598,416
3,256,464
6,026,115
1,464,285
13,338,503
1,901,133

460,380
377,537
361,644
2,233,665

ACCESSORY ELECTRIC EQUIPMENT
TRIMBLE COUNTY UNIT 2
TRIMBLE COUNTY UNIT 2 SCRUBBER
BROWN UNIT 1
BROWN UNIT 2
BROWN UNIT 3
BROWN UNIT 1, 2 AND 3 SCRUBBER
GHENT UNIT 1 SCRUBBER
GHENT UNIT 1
GHENT UNIT 2
GHENT UNIT 3
GHENT UNIT 4
GHENT UNIT 2 SCRUBBER
GHENT UNIT 3 SCRUBBER
GHENT UNIT 4 SCRUBBER

CALCULATED ANNUAL
ACCRUAL
ACCRUAL
AMOUNT
RATE
(7)
(8)=(7)/(4)

FUTURE
ACCRUALS
(6)

4,610,665.23
575,455.72
1,831,840.98
91,265.89
9,299,115.00
3,909,061.67
19,802,080.26
1,777,792.39
32,692,663.87
1,901,133.18

TURBOGENERATOR UNITS - RETIRED PLANT
TYRONE UNIT 3
TYRONE UNITS 1 AND 2
GREEN RIVER UNIT 3
GREEN RIVER UNIT 4

TOTAL ACCOUNT 315 - ACCESSORY ELECTRIC EQUIPMENT
315.10

ORIGINAL
COST
(4)

47,156,606.94
1,415,469.10
4,224,540.53
2,408,998.58
8,959,757.01
29,308,888.08
12,144,071.97
11,725,994.72
14,302,432.69
33,488,118.71
27,465,559.02
951,198.87
12,041,998.28
15,148,041.55

8,082,472
751,018
3,219,138
1,409,941
6,735,226
5,739,630
4,905,197
8,500,593
11,303,320
24,419,733
18,041,343
180,721
3,570,888
2,357,879

44,261,362
820,153
1,216,630
1,119,508
2,672,519
25,034,702
8,088,960
4,046,221
4,000,283
11,412,554
11,346,805
837,062
9,314,050
13,850,525

950,037
20,058
162,781
83,617
138,260
1,291,780
440,467
222,000
225,550
557,910
527,907
45,517
438,601
621,100

2.01
1.42
3.85
3.47
1.54
4.41
3.63
1.89
1.58
1.67
1.92
4.79
3.64
4.10

46.6
40.9
7.5
13.4
19.3
19.4
18.4
18.2
17.7
20.5
21.5
18.4
21.2
22.3

220,741,676.05

99,217,099

138,021,334

5,725,585

2.59

24.1

24,678.67
165,716.59
480,433.11

27,147
182,288
528,476

0
0
0

0
0
0

-

-

670,828.37

737,911

0

0

-

-

Attachment to Response to AG-2 Question No. 33(b)
Page 2 of 7
Spanos

 KENTUCKY UTILITIES

TABLE 1. SUMMARY OF ESTIMATED SURVIVOR CURVES, NET SALVAGE PERCENT, ORIGINAL COST, BOOK DEPRECIATION RESERVE AND
CALCULATED ANNUAL DEPRECIATION ACCRUAL RATES AS OF DECEMBER 31, 2015

ACCOUNT
(1)
316.00

MISCELLANEOUS PLANT EQUIPMENT
TRIMBLE COUNTY UNIT 2
SYSTEM LABORATORY
BROWN UNIT 1
BROWN UNIT 2
BROWN UNIT 3
GHENT UNIT 1 SCRUBBER
GHENT UNIT 1
GHENT UNIT 2
GHENT UNIT 3
GHENT UNIT 4

NET
SALVAGE
PERCENT
(3)

SURVIVOR
CURVE
(2)

75-R1.5
75-R1.5
75-R1.5
75-R1.5
75-R1.5
75-R1.5
75-R1.5
75-R1.5
75-R1.5
75-R1.5

*
*
*
*
*
*
*
*
*
*

(11)
(1)
(5)
(5)
(5)
(7)
(7)
(7)
(7)
(7)

TOTAL ACCOUNT 316 - MISCELLANEOUS PLANT EQUIPMENT
316.10

MISCELLANEOUS PLANT EQUIPMENT - RETIRED PLANT
TYRONE UNIT 3
TYRONE UNITS 1 AND 2
GREEN RIVER UNIT 4
GREEN RIVER UNITS 1 AND 2

75-R1.5
75-R1.5
75-R1.5
75-R1.5

*
*
*
*

(10)
(10)
(10)
(10)

TOTAL ACCOUNT 316.1 - MISCELLANEOUS PLANT EQUIPMENT - RETIRED PLANT
TOTAL STEAM PRODUCTION PLANT

ORIGINAL
COST
(4)

BOOK
DEPRECIATION
RESERVE
(5)

CALCULATED ANNUAL
ACCRUAL
ACCRUAL
AMOUNT
RATE
(7)
(8)=(7)/(4)

FUTURE
ACCRUALS
(6)

COMPOSITE
REMAINING
LIFE
(9)=(6)/(7)

8,369,509.98
3,234,114.29
445,832.67
123,107.10
6,381,168.11
1,033,027.09
1,883,273.64
1,527,545.73
3,984,043.73
8,771,982.95

721,700
901,711
355,631
107,051
3,287,152
948,862
1,666,398
1,449,503
2,671,355
3,568,709

8,568,456
2,364,744
112,493
22,211
3,413,075
156,477
348,705
184,971
1,591,572
5,817,313

188,876
101,143
15,212
1,680
181,900
8,797
19,624
10,632
78,030
271,431

2.26
3.13
3.41
1.36
2.85
0.85
1.04
0.70
1.96
3.09

45.4
23.4
7.4
13.2
18.8
17.8
17.8
17.4
20.4
21.4

35,753,605.29

15,678,072

22,580,017

877,325

2.45

25.7

74,491.69
11,541.15
380,191.26
45,689.51

81,941
12,695
418,210
50,258

0
0
0
0

0
0
0
0

-

-

-

-

511,913.61

563,104

0

0

4,713,368,149.23

1,475,084,816

3,581,288,264

161,456,727

HYDROELECTRIC PRODUCTION PLANT
330.10

LAND RIGHTS
DIX DAM

100-R4

*

0

TOTAL ACCOUNT 330.1 - LAND RIGHTS
331.00

STRUCTURES AND IMPROVEMENTS
DIX DAM

90-S2.5

*

(3)

TOTAL ACCOUNT 331 - STRUCTURES AND IMPROVEMENTS
332.00

RESERVOIRS, DAMS & WATERWAY
DIX DAM

105-S2.5

*

(3)

TOTAL ACCOUNT 332 - RESERVOIRS, DAMS & WATERWAYS
333.00

WATER WHEELS, TURBINES & GENERATORS
DIX DAM

75-R3

*

(3)

TOTAL ACCOUNT 333 - WATER WHEELS, TURBINES & GENERATORS
334.00

ACCESSORY ELECTRIC EQUIPMENT
DIX DAM

40-L2.5

*

(3)

TOTAL ACCOUNT 334 - ACCESSORY ELECTRIC EQUIPMENT
335.00

MISCELLANEOUS POWER PLANT EQUIPMENT
DIX DAM

40-S0

*

(3)

TOTAL ACCOUNT 335 - MISCELLANEOUS POWER PLANT EQUIPMENT
336.00

ROADS, RAILROADS & BRIDGES
DIX DAM

60-R4

*

(3)

TOTAL ACCOUNT 336 - ROADS, RAILROADS & BRIDGES
TOTAL HYDROELECTRIC PRODUCTION PLANT

879,311.47

912,333

(33,022)

0

-

-

879,311.47

912,333

(33,022)

0

-

-

827,602.64

345,562

506,869

20,516

2.48

24.7

827,602.64

345,562

506,869

20,516

2.48

24.7

21,885,646.37

8,216,620

14,325,596

570,125

2.61

25.1

21,885,646.37

8,216,620

14,325,596

570,125

2.61

25.1

14,058,896.32

817,722

13,662,941

542,711

3.86

25.2

14,058,896.32

817,722

13,662,941

542,711

3.86

25.2

1,321,688.77

220,518

1,140,821

50,351

3.81

22.7

1,321,688.77

220,518

1,140,821

50,351

3.81

22.7

316,946.74

116,558

209,897

11,924

3.76

17.6

316,946.74

116,558

209,897

11,924

3.76

17.6

234,509.13

70,567

170,977

7,820

3.33

21.9

234,509.13

70,567

170,977

7,820

3.33

21.9

39,524,601.44

10,699,880

29,984,079

1,203,447

OTHER PRODUCTION PLANT
340.10

LAND RIGHTS
BROWN CT UNIT 9 GAS PIPE
TOTAL ACCOUNT 340.1 - LAND AND LAND RIGHTS

SQUARE

*

0

176,409.31

116,532

59,877

3,863

2.19

15.5

176,409.31

116,532

59,877

3,863

2.19

15.5

Attachment to Response to AG-2 Question No. 33(b)
Page 3 of 7
Spanos

 KENTUCKY UTILITIES

TABLE 1. SUMMARY OF ESTIMATED SURVIVOR CURVES, NET SALVAGE PERCENT, ORIGINAL COST, BOOK DEPRECIATION RESERVE AND
CALCULATED ANNUAL DEPRECIATION ACCRUAL RATES AS OF DECEMBER 31, 2015

ACCOUNT
(1)
341.00

STRUCTURES AND IMPROVEMENTS
CANE RUN CC 7
TRIMBLE COUNTY CT 5
TRIMBLE COUNTY CT 6
TRIMBLE COUNTY CT 7
TRIMBLE COUNTY CT 8
TRIMBLE COUNTY CT 9
TRIMBLE COUNTY CT 10
BROWN CT 5
BROWN CT 6
BROWN CT 7
BROWN CT 8
BROWN CT 9
BROWN CT 10
BROWN CT 11
HAEFLING UNITS 1, 2 AND 3
PADDY'S RUN GENERATOR 13

NET
SALVAGE
PERCENT
(3)

SURVIVOR
CURVE
(2)

50-R2.5
50-R2.5
50-R2.5
50-R2.5
50-R2.5
50-R2.5
50-R2.5
50-R2.5
50-R2.5
50-R2.5
50-R2.5
50-R2.5
50-R2.5
50-R2.5
50-R2.5
50-R2.5

*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*

(10)
(7)
(7)
(7)
(7)
(7)
(7)
(6)
(6)
(6)
(6)
(6)
(6)
(6)
(10)
(6)

TOTAL ACCOUNT 341 - STRUCTURES AND IMPROVEMENTS
342.00

FUEL HOLDERS, PRODUCERS AND ACCESSORIES
CANE RUN CC 7
CANE RUN GAS PIPELINE
TRIMBLE COUNTY CT 5
TRIMBLE COUNTY CT 6
TRIMBLE COUNTY CT PIPELINE
TRIMBLE COUNTY CT 7
TRIMBLE COUNTY CT 8
TRIMBLE COUNTY CT 9
TRIMBLE COUNTY CT 10
BROWN CT 5
BROWN CT 6
BROWN CT 7
BROWN CT 8
BROWN CT 9
BROWN CT 10
BROWN CT 11
BROWN CT UNIT 9 GAS PIPE
HAEFLING UNITS 1, 2 AND 3
PADDY'S RUN GENERATOR 13

45-R2.5
45-R2.5
45-R2.5
45-R2.5
45-R2.5
45-R2.5
45-R2.5
45-R2.5
45-R2.5
45-R2.5
45-R2.5
45-R2.5
45-R2.5
45-R2.5
45-R2.5
45-R2.5
45-R2.5
45-R2.5
45-R2.5

*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*

(10)
(10)
(7)
(7)
(7)
(7)
(7)
(7)
(7)
(6)
(6)
(6)
(6)
(6)
(6)
(6)
(6)
(10)
(6)

TOTAL ACCOUNT 342 - FUEL HOLDERS, PRODUCERS AND ACCESSORIES
343.00

PRIME MOVERS
CANE RUN CC 7
TRIMBLE COUNTY CT 5
TRIMBLE COUNTY CT 6
TRIMBLE COUNTY CT 7
TRIMBLE COUNTY CT 8
TRIMBLE COUNTY CT 9
TRIMBLE COUNTY CT 10
BROWN CT 5
BROWN CT 6
BROWN CT 7
BROWN CT 8
BROWN CT 9
BROWN CT 10
BROWN CT 11
PADDY'S RUN GENERATOR 13

35-R1.5
35-R1.5
35-R1.5
35-R1.5
35-R1.5
35-R1.5
35-R1.5
35-R1.5
35-R1.5
35-R1.5
35-R1.5
35-R1.5
35-R1.5
35-R1.5
35-R1.5

*
*
*
*
*
*
*
*
*
*
*
*
*
*
*

(10)
(7)
(7)
(7)
(7)
(7)
(7)
(6)
(6)
(6)
(6)
(6)
(6)
(6)
(6)

TOTAL ACCOUNT 343 - PRIME MOVERS
344.00

GENERATORS
CANE RUN CC 7
TRIMBLE COUNTY CT 5
TRIMBLE COUNTY CT 6
TRIMBLE COUNTY CT 7
TRIMBLE COUNTY CT 8
TRIMBLE COUNTY CT 9
TRIMBLE COUNTY CT 10

55-S2.5
55-S2.5
55-S2.5
55-S2.5
55-S2.5
55-S2.5
55-S2.5

*
*
*
*
*
*
*

(10)
(7)
(7)
(7)
(7)
(7)
(7)

ORIGINAL
COST
(4)

BOOK
DEPRECIATION
RESERVE
(5)

FUTURE
ACCRUALS
(6)

CALCULATED ANNUAL
ACCRUAL
ACCRUAL
AMOUNT
RATE
(7)
(8)=(7)/(4)

COMPOSITE
REMAINING
LIFE
(9)=(6)/(7)

46,895,473.79
3,740,231.32
3,588,684.24
3,559,154.97
3,548,851.71
3,655,976.41
3,653,029.99
785,900.23
192,814.02
567,512.07
2,012,654.95
4,660,156.04
1,865,718.20
1,919,015.13
291,451.55
2,136,302.83

663,228
1,711,412
1,647,141
1,423,558
1,419,437
1,452,931
1,451,760
380,011
97,181
287,418
1,419,091
3,115,511
1,202,272
1,208,894
71,390
936,648

50,921,793
2,290,636
2,192,751
2,384,738
2,377,834
2,458,964
2,456,982
453,043
107,202
314,145
714,323
1,824,254
775,389
825,262
249,207
1,327,833

1,395,882
144,628
138,513
134,503
134,114
138,689
138,578
30,420
8,215
24,111
77,708
125,197
53,217
81,069
55,881
88,832

2.98
3.87
3.86
3.78
3.78
3.79
3.79
3.87
4.26
4.25
3.86
2.69
2.85
4.22
19.17
4.16

36.5
15.8
15.8
17.7
17.7
17.7
17.7
14.9
13.0
13.0
9.2
14.6
14.6
10.2
4.5
14.9

83,072,927.45

18,487,883

71,674,356

2,769,557

3.33

25.9

111,535,551.95
23,414,526.87
239,584.43
239,245.54
4,856,134.65
578,059.38
576,385.74
593,786.01
622,872.60
795,787.89
959,617.20
959,028.11
263,045.52
3,155,168.57
282,445.64
301,560.87
8,208,122.69
472,116.83
1,997,091.15

1,643,640
345,052
110,150
110,006
2,216,039
231,910
231,239
236,879
246,641
261,412
141,990
138,794
120,424
1,205,201
71,115
92,783
5,255,746
192,271
975,255

121,045,467
25,410,928
146,205
145,987
2,980,025
386,614
385,494
398,472
419,833
582,123
875,204
877,776
158,404
2,139,278
228,277
226,872
3,444,864
327,058
1,141,662

3,397,291
713,189
9,354
9,340
171,646
22,080
22,016
22,757
23,962
39,251
66,086
66,279
16,886
144,655
15,153
21,981
242,700
74,299
77,700

3.05
3.05
3.90
3.90
3.53
3.82
3.82
3.83
3.85
4.93
6.89
6.91
6.42
4.58
5.36
7.29
2.96
15.74
3.89

35.6
35.6
15.6
15.6
17.4
17.5
17.5
17.5
17.5
14.8
13.2
13.2
9.4
14.8
15.1
10.3
14.2
4.4
14.7

160,050,131.64

13,826,547

161,320,543

5,156,625

3.22

31.3

89,873,336.88
33,056,281.24
32,944,728.98
26,290,569.66
25,158,461.82
24,889,310.25
24,739,825.43
14,722,669.92
34,702,471.57
31,876,587.22
26,679,925.25
28,711,611.96
25,926,887.42
34,682,773.23
19,558,876.85

1,353,524
13,187,243
13,527,496
8,647,624
8,098,854
8,411,416
8,285,715
6,777,304
14,206,645
13,616,280
14,860,849
12,156,038
10,072,720
21,054,696
5,651,832

97,507,147
22,182,978
21,723,364
19,483,286
18,820,700
18,220,146
18,185,898
8,828,726
22,577,975
20,172,902
13,419,872
18,278,271
17,409,781
15,709,044
15,080,577

3,154,550
1,513,668
1,483,363
1,188,928
1,150,385
1,114,728
1,111,919
638,782
1,851,313
1,657,646
1,519,224
1,338,860
1,260,560
1,636,017
1,081,308

3.51
4.58
4.50
4.52
4.57
4.48
4.49
4.34
5.33
5.20
5.69
4.66
4.86
4.72
5.53

30.9
14.7
14.6
16.4
16.4
16.3
16.4
13.8
12.2
12.2
8.8
13.7
13.8
9.6
13.9

473,814,317.68

159,908,236

347,600,667

21,701,251

4.58

16.0

113,390,206.33
3,800,400.42
3,795,072.48
2,983,225.97
2,970,873.80
2,990,463.70
2,987,092.13

1,903,560
1,691,733
1,689,538
1,154,958
1,150,135
1,150,226
1,149,086

122,825,667
2,374,695
2,371,190
2,037,094
2,028,700
2,049,570
2,047,103

3,218,702
146,280
146,065
111,785
111,325
112,470
112,335

2.84
3.85
3.85
3.75
3.75
3.76
3.76

38.2
16.2
16.2
18.2
18.2
18.2
18.2

Attachment to Response to AG-2 Question No. 33(b)
Page 4 of 7
Spanos

 KENTUCKY UTILITIES

TABLE 1. SUMMARY OF ESTIMATED SURVIVOR CURVES, NET SALVAGE PERCENT, ORIGINAL COST, BOOK DEPRECIATION RESERVE AND
CALCULATED ANNUAL DEPRECIATION ACCRUAL RATES AS OF DECEMBER 31, 2015

ACCOUNT
(1)
BROWN CT 5
BROWN CT 6
BROWN CT 7
BROWN CT 8
BROWN CT 9
BROWN CT 10
BROWN CT 11
HAEFLING UNITS 1, 2 AND 3
PADDY'S RUN GENERATOR 13

NET
SALVAGE
PERCENT
(3)

SURVIVOR
CURVE
(2)
55-S2.5
55-S2.5
55-S2.5
55-S2.5
55-S2.5
55-S2.5
55-S2.5
55-S2.5
55-S2.5

*
*
*
*
*
*
*
*
*

(6)
(6)
(6)
(6)
(6)
(6)
(6)
(10)
(6)

TOTAL ACCOUNT 344 - GENERATORS
345.00

ACCESSORY ELECTRIC EQUIPMENT
CANE RUN CC 7
TRIMBLE COUNTY CT 5
TRIMBLE COUNTY CT 6
TRIMBLE COUNTY CT 7
TRIMBLE COUNTY CT 8
TRIMBLE COUNTY CT 9
TRIMBLE COUNTY CT 10
BROWN CT 5
BROWN CT 6
BROWN CT 7
BROWN CT 8
BROWN CT 9
BROWN CT 10
BROWN CT 11
HAEFLING UNITS 1, 2 AND 3
PADDY'S RUN GENERATOR 13

50-R3
50-R3
50-R3
50-R3
50-R3
50-R3
50-R3
50-R3
50-R3
50-R3
50-R3
50-R3
50-R3
50-R3
50-R3
50-R3

*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*

(10)
(7)
(7)
(7)
(7)
(7)
(7)
(6)
(6)
(6)
(6)
(6)
(6)
(6)
(10)
(6)

TOTAL ACCOUNT 345 - ACCESSORY ELECTRIC EQUIPMENT
346.00

MISCELLANEOUS PLANT EQUIPMENT
CANE RUN CC 7
TRIMBLE COUNTY CT 5
TRIMBLE COUNTY CT 7
TRIMBLE COUNTY CT 8
TRIMBLE COUNTY CT 9
TRIMBLE COUNTY CT 10
BROWN CT 5
BROWN CT 6
BROWN CT 7
BROWN CT 8
BROWN CT 9
BROWN CT 10
BROWN CT 11
HAEFLING UNITS 1, 2 AND 3
PADDY'S RUN GENERATOR 13

40-R2
40-R2
40-R2
40-R2
40-R2
40-R2
40-R2
40-R2
40-R2
40-R2
40-R2
40-R2
40-R2
40-R2
40-R2

*
*
*
*
*
*
*
*
*
*
*
*
*
*
*

(10)
(7)
(7)
(7)
(7)
(7)
(6)
(6)
(6)
(6)
(6)
(6)
(6)
(10)
(6)

TOTAL ACCOUNT 346 - MISCELLANEOUS PLANT EQUIPMENT
TOTAL OTHER PRODUCTION PLANT

ORIGINAL
COST
(4)

BOOK
DEPRECIATION
RESERVE
(5)

FUTURE
ACCRUALS
(6)

CALCULATED ANNUAL
ACCRUAL
ACCRUAL
AMOUNT
RATE
(7)
(8)=(7)/(4)

COMPOSITE
REMAINING
LIFE
(9)=(6)/(7)

2,866,821.78
3,721,293.63
3,731,462.57
4,962,634.83
5,460,715.08
4,953,096.82
5,762,894.98
2,682,135.68
5,450,549.42

1,327,386
1,994,405
1,971,763
3,437,474
3,599,863
3,129,054
2,847,510
2,341,531
2,269,181

1,711,445
1,950,166
1,983,587
1,822,919
2,188,495
2,121,229
3,261,159
608,818
3,508,401

112,236
146,951
149,464
195,161
147,437
142,251
314,407
143,904
229,696

3.91
3.95
4.01
3.93
2.70
2.87
5.46
5.37
4.21

15.2
13.3
13.3
9.3
14.8
14.9
10.4
4.2
15.3

172,508,939.62

32,807,403

154,890,238

5,540,469

3.21

28.0

26,286,452.56
1,889,943.86
4,329,841.09
3,833,038.02
3,144,581.31
3,423,274.57
7,261,076.07
2,310,232.75
2,026,642.95
1,987,208.52
3,326,335.69
4,707,156.48
3,245,891.87
2,454,258.42
816,263.41
2,499,650.62

421,424
754,635
1,688,232
1,250,888
1,229,820
1,257,225
2,513,401
1,003,516
987,425
966,000
1,750,769
2,494,754
1,659,633
1,381,238
105,619
1,141,302

28,493,674
1,267,605
2,944,698
2,850,463
2,134,882
2,405,679
5,255,950
1,445,331
1,160,817
1,140,441
1,775,147
2,494,832
1,781,012
1,220,276
792,271
1,508,328

764,931
78,966
184,149
158,187
119,062
133,945
293,027
96,109
88,478
86,959
190,725
168,092
120,084
118,281
180,894
100,236

2.91
4.18
4.25
4.13
3.79
3.91
4.04
4.16
4.37
4.38
5.73
3.57
3.70
4.82
22.16
4.01

37.2
16.1
16.0
18.0
17.9
18.0
17.9
15.0
13.1
13.1
9.3
14.8
14.8
10.3
4.4
15.0

73,541,848.19

20,605,881

58,671,406

2,882,125

3.92

20.4

21,065.55
28,963.63
8,888.93
8,861.01
9,113.52
41,868.51
2,139,352.61
102,224.96
84,123.48
291,226.01
860,425.29
274,390.87
590,562.82
104,991.22
1,089,550.03

88
12,880
3,661
3,649
3,730
11,271
1,067,229
26,854
21,717
180,825
524,836
170,711
323,816
35,538
546,300

23,084
18,111
5,850
5,832
6,021
33,528
1,200,485
81,504
67,454
127,875
387,215
120,143
302,181
79,952
608,623

688
1,169
346
345
356
1,930
84,301
6,279
5,183
14,179
27,811
8,737
30,208
18,636
42,769

3.27
4.04
3.89
3.89
3.91
4.61
3.94
6.14
6.16
4.87
3.23
3.18
5.12
17.75
3.93

33.6
15.5
16.9
16.9
16.9
17.4
14.2
13.0
13.0
9.0
13.9
13.8
10.0
4.3
14.2

4.30

12.6

0.86
1.66
1.83
1.90
1.69
2.93
2.54
1.70
0.74

48.9
59.5
47.9
46.0
44.8
48.8
43.8
28.7
23.6

5,655,608.44

2,933,105

3,067,858

242,937

968,820,182.33

248,685,587

797,284,945

38,296,827

29,428,995.30
25,314,463.82
193,226.01
257,735,637.27
6,568,060.27
76,403,298.64
228,799,845.74
178,542,714.22
448,760.26
1,173,303.32

17,044,058
6,625,682
71,970
70,441,066
7,553,269
49,143,732
72,993,220
114,190,318
229,646
966,623

12,384,937
25,017,398
169,563
225,954,917
0
57,820,886
327,406,510
198,259,432
219,114
206,680

253,363
420,302
3,543
4,908,788
0
1,289,330
6,711,919
4,527,061
7,645
8,740

804,608,304.85

339,259,584

847,439,437

18,130,691

TRANSMISSION PLANT
350.10
352.10
352.20
353.10
353.20
354.00
355.00
356.00
357.00
358.00

LAND AND LAND RIGHTS
STRUCTURES & IMPROVEMENTS - NON SYS CONTROL/COM
STRUCTURES & IMPROVEMENTS - SYS CONTROL/COM
STATION EQUIPMENT - NON SYS CONTROL/COM
STATION EQUIPMENT - SYS CONTROL/COM
TOWERS AND FIXTURES
POLES AND FIXTURES
OVERHEAD CONDUCTORS AND DEVICES
UNDERGROUND CONDUIT
UNDERGROUND CONDUCTORS AND DEVICES
TOTAL TRANSMISSION PLANT

70-R3
70-R3
65-R4
60-R2
45-R2
70-R4
58-R2
65-R3
50-R4
40-R3

0
(25)
(25)
(15)
(15)
(40)
(75)
(75)
0
0

Attachment to Response to AG-2 Question No. 33(b)
Page 5 of 7
Spanos

 KENTUCKY UTILITIES

TABLE 1. SUMMARY OF ESTIMATED SURVIVOR CURVES, NET SALVAGE PERCENT, ORIGINAL COST, BOOK DEPRECIATION RESERVE AND
CALCULATED ANNUAL DEPRECIATION ACCRUAL RATES AS OF DECEMBER 31, 2015

ACCOUNT
(1)

SURVIVOR
CURVE
(2)

NET
SALVAGE
PERCENT
(3)

70-R4
60-R2.5
54-R2
50-R1.5
47-R1
50-R4
48-R2
46-R2
48-R1
28-L1
28-L1

0
(25)
(20)
(50)
(30)
0
(20)
(5)
(25)
0
0

2,168,929.31
10,718,796.73
173,228,756.89
354,797,240.32
337,937,644.27
2,050,521.69
181,393,660.79
308,054,000.11
94,875,368.05
66,212,808.46
10,416,674.08

0
(10)
(10)

698,893.34
17,054,091.74
95,997,822.30

ORIGINAL
COST
(4)

BOOK
DEPRECIATION
RESERVE
(5)

FUTURE
ACCRUALS
(6)

CALCULATED ANNUAL
ACCRUAL
ACCRUAL
AMOUNT
RATE
(7)
(8)=(7)/(4)

COMPOSITE
REMAINING
LIFE
(9)=(6)/(7)

DISTRIBUTION PLANT
360.10
361.00
362.00
364.00
365.00
366.00
367.00
368.00
369.00
370.00
370.10
370.20
371.00
373.00

LAND AND LAND RIGHTS
STRUCTURES AND IMPROVEMENTS
STATION EQUIPMENT
POLES, TOWERS, AND FIXTURES
OVERHEAD CONDUCTORS AND DEVICES
UNDERGROUND CONDUIT
UNDERGROUND CONDUCTORS AND DEVICES
LINE TRANSFORMERS
SERVICES
METERS
METERING EQUIPMENT
METERS - RESERVE AMORTIZATION
METERS - AMS
INSTALLATIONS ON CUSTOMERS' PREMISES
STREET LIGHTING AND SIGNAL SYSTEMS

15-S2.5
28-O1
28-L0.5

*

TOTAL DISTRIBUTION PLANT

1,458,105
2,256,794
47,843,031
152,141,111
119,403,224
832,564
40,586,062
141,176,694
61,837,515
56,280,887
3,863,114
(22,208,790)
4,284
17,012,710
20,947,022

710,824
11,141,702
160,031,477
380,054,749
319,915,714
1,217,958
177,086,331
182,280,006
56,756,695
9,931,921
6,553,560
22,208,790
694,609
1,746,791
84,650,583

13,823
230,057
3,967,466
9,477,978
8,351,144
47,571
4,406,186
5,515,604
1,549,728
2,326,567
447,268
***
47,904
90,485
3,837,892

1,655,605,208.08

643,434,327

1,414,981,710

40,309,673

56,676,361.14
528,658.33
9,997,759.47
26,955,602.79
7,487,177.86
1,080,256.71
4,496,087.64
1,504,425.91
12,146,898.05
2,293,200.28
25,857,151.87
20,009,653.11
5,875,508.03

11,157,166
445,844
5,677,517
14,275,399
3,350,909
850,491
2,506,216
311,738
3,584,231
733,922
8,888,012
7,845,508
497,906

54,020,649
135,680
4,320,242
12,680,204
4,136,269
229,766
1,989,872
1,192,688
8,562,667
1,559,278
16,969,140
12,164,145
5,377,602

1,378,746
7,551
435,890
3,152,434
1,873,226
21,335
143,633
66,208
488,036
129,523
1,268,220
2,169,315
827,323

174,908,741.19

60,124,859

123,338,202

11,961,440

8,449,146,032.44

2,821,716,576

6,842,199,960

286,223,655

2,821,716,576

6,842,199,960

286,223,655

0.64
2.15
2.29
2.67
2.47
2.32
2.43
1.79
1.63
3.51
4.29
6.85
0.53
4.00

51.4
48.4
40.3
40.1
38.3
25.6
40.2
33.0
36.6
4.3
14.7

2.43
1.43
4.36
11.69
25.02
1.97
3.19
4.40
4.02
5.65
4.90
10.84
14.08

39.2
18.0
9.9
4.0
2.2
10.8
13.9
18.0
17.5
12.0
13.4
5.6
6.5

14.5
19.3
22.1

GENERAL PLANT
390.10
390.20
391.10
391.20
391.31
392.00
392.10
393.00
394.00
396.00
397.00
397.10
397.20

STRUCTURES AND IMPROVEMENTS - TO OWNED PROPERTY
STRUCTURES AND IMPROVEMENTS - LEASEHOLDS
OFFICE FURNITURE AND EQUIPMENT
NON PC COMPUTER EQUIPMENT
PERSONAL COMPUTERS
TRANSPORTATION EQUIPMENT - CARS AND LIGHT TRUCKS
TRANSPORTATION EQUIPMENT - HEAVY TRUCKS AND OTHER
STORES EQUIPMENT
TOOLS, SHOP AND GARAGE EQUIPMENT
POWER OPERATED EQUIPMENT
COMMUNICATION EQUIPMENT - MICROWAVE, FIBER AND OTHER
COMMUNICATION EQUIPMENT - RADIO AND TELEPHONE
COMMUNICATION EQUIPMENT - DSM

50-S0
33-R1.5
20-SQ
5-SQ
4-SQ
14-S2
16-L2.5
25-SQ
25-SQ
16-L5
18-L3
10-SQ
10-SQ

TOTAL GENERAL PLANT
TOTAL DEPRECIABLE PLANT

(15)
(10)
0
0
0
0
0
0
0
0
0
0
0

NONDEPRECIABLE PLANT
301.00
310.20
340.20
350.20
360.20
389.20

ORGANIZATION
LAND
LAND
LAND
LAND
LAND
TOTAL NONDEPRECIABLE PLANT
TOTAL ELECTRIC PLANT

44,455.58
22,958,202.42
135,099.02
2,360,270.07
5,673,927.95
2,810,081.60
33,982,036.64
8,483,128,069.08

* LIFE SPAN PROCEDURE IS USED. CURVE SHOWN IS INTERIM SURVIVOR CURVE
** TERMINAL NET SALVAGE FACTOR WHICH IS BASED ON VINTAGE AND FUTURE COSTS
*** RESERVE AMOUNT TO BE RECOVERED AT END OF REPLACEMENT PROGRAM
NOTE:

Accrual rates for the Brown Solar Assets when placed in service June 2016 wil be as follows:
Account
Rate
34100
4.24%
34400
4.61%
34500
4.36%
34600
4.25%
Accrual rates for the Electric Vehicle Charging Station Assets when placed in service June 2016 wil be as follows:
Account
Rate
37100
10.00%

Attachment to Response to AG-2 Question No. 33(b)
Page 6 of 7
Spanos

 KENTUCKY UTILITIES

TABLE 1. SUMMARY OF ESTIMATED SURVIVOR CURVES, NET SALVAGE PERCENT, ORIGINAL COST, BOOK DEPRECIATION RESERVE AND
CALCULATED ANNUAL DEPRECIATION ACCRUAL RATES AS OF DECEMBER 31, 2015

ACCOUNT
(1)

SURVIVOR
CURVE
(2)

NET
SALVAGE
PERCENT
(3)

ORIGINAL
COST
(4)

BOOK
DEPRECIATION
RESERVE
(5)

FUTURE
ACCRUALS
(6)

CALCULATED ANNUAL
ACCRUAL
ACCRUAL
AMOUNT
RATE
(7)
(8)=(7)/(4)

COMPOSITE
REMAINING
LIFE
(9)=(6)/(7)

Attachment to Response to AG-2 Question No. 33(b)
Page 7 of 7
Spanos

 Attachment to Response to AG-2 Question No. 33(c)
Page 1 of 149
Spanos

SURVIVOR CURVE.. 20-SQUARE
NET SALVAGE PERCENT.. 0
1991
1992
1993
1995
1996
1997
1998
1999
2002
2003

1,588.57
792.28
6,183.50
30,302.58
10,457.30
1,725.32
2,055.48
711.08
585.80
1,516.92

1,589
792
6,184
30,303
10,196
1,596
1,799
587
395
948

1,589
792
6,184
30,303
9,006
1,410
1,589
519
349
837

1,451
315
466
192
237
680

55,918.83

54,389

52,578

3,341

0.50
1.50
2.50
3.50
6.50
7.50

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 1.6

1,451
210
186
55
36
91
2,029
3.63

 Attachment to Response to AG-2 Question No. 33(c)
Page 2 of 149
Spanos

SURVIVOR CURVE.. 5-SQUARE
NET SALVAGE PERCENT.. 0
2010
2011
2012
2013
2014
2015

180,984.56
5,389,063.29
7,676,028.89
7,139,348.90
12,768,962.93
18,055,043.39

180,985
4,850,157
5,373,220
3,569,674
3,830,689
1,805,504

180,985
4,395,288
4,869,296
3,234,895
3,471,430
1,636,176

993,775
2,806,733
3,904,454
9,297,533
16,418,867

51,209,431.96

19,610,229

17,788,070

33,421,362

0.50
1.50
2.50
3.50
4.50

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 3.1

993,775
1,871,155
1,561,782
2,656,438
3,648,637
10,731,787
20.96

 Attachment to Response to AG-2 Question No. 33(c)
Page 3 of 149
Spanos

INTERIM SURVIVOR CURVE.. SQUARE
PROBABLE RETIREMENT YEAR.. 6-2019
NET SALVAGE PERCENT.. 0
2009
2010
2011
2013

36,405,085.42
979,128.50
2,499,552.85
1,161,727.76

23,663,306
598,355
1,405,998
484,057

24,057,058
608,312
1,429,393
492,112

12,348,027
370,816
1,070,160
669,616

41,045,494.53

26,151,716

26,586,875

14,458,620

3.50
3.50
3.50
3.50

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 3.5

3,528,008
105,947
305,760
191,319
4,131,034
10.06

 Attachment to Response to AG-2 Question No. 33(c)
Page 4 of 149
Spanos

TRIMBLE COUNTY UNIT 2
INTERIM SURVIVOR CURVE.. IOWA 100-R2.5
PROBABLE RETIREMENT YEAR.. 6-2066
NET SALVAGE PERCENT.. -11
1990
1997
2002
2003
2008
2011
2012
2013
2014
2015

34,905,872.19
449,904.13
24,848.68
61,493.38
53,301.70
59,176,473.13
377,820.80
79,448.45
158,517.38
246,069.29

13,188,587
135,301
5,864
13,654
7,702
5,406,605
27,323
4,179
5,101
2,707

16,449,824
168,758
7,314
17,030
9,607
6,743,535
34,079
5,212
6,362
3,376

22,295,694
330,636
20,268
51,227
49,558
58,942,350
385,302
82,975
169,592
269,761

95,533,749.13

18,797,023

23,445,099

82,597,363

46.74
47.55
48.03
48.11
48.51
48.72
48.79
48.85
48.91
48.97

477,015
6,953
422
1,065
1,022
1,209,818
7,897
1,699
3,467
5,509
1,714,867

TRIMBLE COUNTY UNIT 2 SCRUBBER
INTERIM SURVIVOR CURVE.. IOWA 100-R2.5
PROBABLE RETIREMENT YEAR.. 6-2066
NET SALVAGE PERCENT.. -11
1990
2012

5,493,644.11
62,807.35

2,075,679
4,542

3,076,062
6,731

3,021,883
62,985

5,556,451.46

2,080,221

3,082,793

3,084,868

46.74
48.79

64,653
1,291
65,944

SYSTEM LABORATORY
INTERIM SURVIVOR CURVE.. IOWA 100-R2.5
PROBABLE RETIREMENT YEAR.. 6-2040
NET SALVAGE PERCENT.. -1
1989
1990
1994
1997
2011
2012
2014
2015

724,776.82
58,100.00
6,176.00
16,663.00
19,253.00
255,306.75
8,935.37
13,745.45

379,035
29,824
2,905
7,214
3,007
32,140
519
280

594,527
46,780
4,557
11,315
4,717
50,412
814
439

137,498
11,901
1,681
5,514
14,729
207,447
8,211
13,444

1,102,956.39

454,924

713,561

400,425

23.85
23.87
23.96
24.02
24.22
24.23
24.25
24.26

5,765
499
70
230
608
8,562
339
554
16,627

 Attachment to Response to AG-2 Question No. 33(c)
Page 5 of 149
Spanos

BROWN UNIT 1
INTERIM SURVIVOR CURVE.. IOWA 100-R2.5
PROBABLE RETIREMENT YEAR.. 6-2023
NET SALVAGE PERCENT.. -5
1948
1956
1958
1965
1979
1982
1983
1984
1985
1987
1988
1989
1990
1991
1994
1995
1996
1997
1998
2004
2005
2006
2007
2008
2014
2015

11,983.27
2,427,156.54
382.11
283.00
14,516.00
91,160.00
1,965.00
5,212.00
1,849.00
43,137.68
45,243.11
64,194.00
658.09
23,174.40
666,989.00
352,899.61
94,854.89
72,522.04
11,065.00
108,817.17
71,616.67
35,830.85
85,296.44
436,431.15
8,914.20
13,918.24

11,273
2,254,161
354
258
12,607
77,980
1,672
4,408
1,554
35,762
37,229
52,405
533
18,587
517,984
270,679
71,780
54,071
8,113
69,027
43,799
20,971
47,455
228,512
1,563
916

12,582
2,548,514
401
297
15,242
95,718
2,063
5,473
1,941
45,295
47,505
67,404
691
24,333
700,338
370,545
99,598
76,148
11,618
114,258
75,198
37,622
86,232
415,237
2,840
1,664

3,329
43,015
6,520
12,950

4,690,069.46

3,843,653

4,858,759

65,814

BROWN UNIT 2
INTERIM SURVIVOR CURVE.. IOWA 100-R2.5
PROBABLE RETIREMENT YEAR.. 6-2029
NET SALVAGE PERCENT.. -5
1963
1965
1966
1967
1979
1980

1,268,530.68
11,653.00
10,986.00
2,142.72
24,545.95
400.00

1,054,311
9,610
9,021
1,752
18,738
303

1,331,957
12,236
11,535
2,250
25,773
420

7.48
7.48
7.48
7.48

445
5,751
872
1,731
8,799

 Attachment to Response to AG-2 Question No. 33(c)
Page 6 of 149
Spanos

BROWN UNIT 2
INTERIM SURVIVOR CURVE.. IOWA 100-R2.5
PROBABLE RETIREMENT YEAR.. 6-2029
NET SALVAGE PERCENT.. -5
1983
1992
1997
2004
2005
2007
2009
2012
2015

1,964.15
96,409.90
19,477.46
43,200.52
5,793.58
565,018.59
21,690.24
133,555.40
91,828.24

1,451
64,053
11,785
20,811
2,653
228,391
7,385
28,794
3,459

2,062
101,230
20,253
35,764
4,559
392,493
12,691
49,483
5,944

199
9,597
1,524
200,777
10,084
90,750
90,475

2,297,196.43

1,462,517

2,008,651

403,405

13.37
13.40
13.41
13.42
13.42
13.43
13.44

15
716
114
14,961
751
6,757
6,732
30,046

BROWN UNIT 3
INTERIM SURVIVOR CURVE.. IOWA 100-R2.5
PROBABLE RETIREMENT YEAR.. 6-2035
NET SALVAGE PERCENT.. -5
1967
1968
1971
1972
1973
1974
1975
1977
1979
1980
1983
1984
1985
1986
1987
1988
1989
1990
1991
1992
1993
1995
1997

1,440.97
93.83
7,455,327.76
56,652.66
11,995.55
2,999.00
15,098.31
1,211,596.00
8,850.03
275,262.00
3,928.40
146,459.90
58,036.00
44,536.07
251,180.26
56,900.74
477,066.00
48,018.29
68,381.00
756,531.00
84,689.00
22,964.00
215,113.23

1,074
70
5,419,390
40,900
8,599
2,133
10,656
841,048
6,033
185,806
2,567
94,583
37,022
28,036
155,983
34,819
287,483
28,454
39,826
432,321
47,448
12,311
109,515

1,372
89
6,924,673
52,260
10,987
2,725
13,616
1,074,656
7,709
237,415
3,280
120,854
47,305
35,823
199,309
44,490
367,334
36,357
50,888
552,402
60,627
15,730
139,934

141
9
903,422
7,225
1,608
423
2,237
197,519
1,584
51,610
845
32,929
13,633
10,940
64,431
15,255
133,585
14,062
20,912
241,956
28,296
8,382
85,935

18.66
18.69
18.77
18.79
18.81
18.84
18.86
18.90
18.94
18.96
19.02
19.04
19.05
19.07
19.08
19.10
19.11
19.13
19.14
19.16
19.17
19.19
19.22

8
48,131
385
85
22
119
10,451
84
2,722
44
1,729
716
574
3,377
799
6,990
735
1,093
12,628
1,476
437
4,471

 Attachment to Response to AG-2 Question No. 33(c)
Page 7 of 149
Spanos

BROWN UNIT 3
INTERIM SURVIVOR CURVE.. IOWA 100-R2.5
PROBABLE RETIREMENT YEAR.. 6-2035
NET SALVAGE PERCENT.. -5
1998
2001
2003
2004
2005
2007
2009
2010
2011
2012
2013
2014
2015

127,955.64
83,885.45
193,441.22
122,280.23
95,151.19
8,016,945.98
200,931.69
423,902.15
43,327.16
602,913.83
504,143.53
966,396.11
57,124.43

63,278
37,410
79,056
47,471
34,843
2,545,372
52,561
97,614
8,494
96,067
59,922
72,065
1,510

80,854
47,801
101,014
60,656
44,521
3,252,371
67,160
124,727
10,853
122,750
76,566
92,082
1,929

53,499
40,279
102,099
67,738
55,388
5,165,422
143,818
320,370
34,640
510,309
452,785
922,634
58,051

22,711,518.61

11,021,740

14,083,124

9,763,971

19.23
19.26
19.27
19.28
19.29
19.31
19.32
19.33
19.34
19.34
19.35
19.36
19.36

2,782
2,091
5,298
3,513
2,871
267,500
7,444
16,574
1,791
26,386
23,400
47,657
2,999
507,382

BROWN UNITS 1, 2 AND 3 SCRUBBER
INTERIM SURVIVOR CURVE.. IOWA 100-R2.5
PROBABLE RETIREMENT YEAR.. 6-2035
NET SALVAGE PERCENT.. -5
1994
2013
2015

38,344.63
45,322,523.30
146,854.51

21,028
5,387,035
3,883

34,098
8,735,324
6,296

6,164
38,853,326
147,901

45,507,722.44

5,411,946

8,775,718

39,007,391

19.18
19.35
19.36

321
2,007,924
7,640
2,015,885

GHENT UNIT 1 SCRUBBER
INTERIM SURVIVOR CURVE.. IOWA 100-R2.5
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
1997
2007

8,362,584.36
34,607.76

4,455,550
11,618

7,312,037
19,066

1,635,929
17,964

8,397,192.12

4,467,168

7,331,103

1,653,893

18.25
18.33

89,640
980
90,620

 Attachment to Response to AG-2 Question No. 33(c)
Page 8 of 149
Spanos

GHENT UNIT 1
INTERIM SURVIVOR CURVE.. IOWA 100-R2.5
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
1974
1979
1980
1981
1985
1987
1988
1992
1994
1995
1996
1997
2003
2005
2007
2009
2010
2011
2013
2015

14,792,573.62
287,003.73
27,171.00
10,791.00
107,260.53
218,325.45
97,360.62
29,300.00
74,968.00
60,912.73
393,716.22
33,704.37
143,388.86
240,490.70
240,638.23
333,988.93
643,507.32
670,518.89
237,388.65
862,032.52

10,900,464
202,915
19,035
7,484
71,146
141,095
62,041
17,476
42,941
34,121
215,323
17,958
61,642
92,781
80,783
92,662
157,224
140,033
30,105
23,954

15,828,054
307,094
28,825
11,333
107,736
213,660
93,949
26,464
65,026
51,669
326,064
27,194
93,344
140,498
122,330
140,318
238,084
212,052
45,588
36,274

248
213
7,032
19,948
10,227
4,887
15,190
13,507
95,213
8,870
60,082
116,827
135,153
217,050
450,469
505,403
208,418
886,101

19,505,041.37

12,411,183

18,115,555

2,754,839

18.02
18.04
18.10
18.13
18.14
18.19
18.22
18.23
18.24
18.25
18.30
18.32
18.33
18.34
18.35
18.35
18.37
18.38

14
12
389
1,100
564
269
834
741
5,220
486
3,283
6,377
7,373
11,835
24,549
27,542
11,346
48,210
150,144

GHENT UNIT 2
INTERIM SURVIVOR CURVE.. IOWA 100-R2.5
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
1977
1979
1980
1981
1986
1988
1989
1991
1995
1997
1998

14,862,896.44
227,477.00
88,059.38
10,786.00
385,657.47
13,292.75
11,294.78
1,929.73
27,739.56
13,603.48
67,159.90

10,695,923
160,829
61,690
7,481
252,540
8,471
7,087
1,172
15,539
7,248
34,794

13,639,097
205,084
78,665
9,540
322,031
10,802
9,037
1,494
19,815
9,242
44,368

2,264,202
38,316
15,558
2,001
90,623
3,421
3,048
570
9,866
5,313
27,493

17.97
18.01
18.02
18.04
18.12
18.14
18.16
18.18
18.23
18.25
18.26

125,999
2,127
863
111
5,001
189
168
31
541
291
1,506

 Attachment to Response to AG-2 Question No. 33(c)
Page 9 of 149
Spanos

GHENT UNIT 2
INTERIM SURVIVOR CURVE.. IOWA 100-R2.5
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
2003
2013
2015

223,834.88
194,635.03
130,289.29

96,225
24,683
3,620

122,703
31,475
4,616

116,800
176,785
134,793

16,258,655.69

11,377,302

14,507,970

2,888,792

18.30
18.37
18.38

6,383
9,624
7,334
160,168

GHENT UNIT 3
INTERIM SURVIVOR CURVE.. IOWA 100-R2.5
PROBABLE RETIREMENT YEAR.. 6-2037
NET SALVAGE PERCENT.. -7
1981
1982
1983
1987
1995
1996
2001
2002
2004
2005
2010
2011
2014

34,380,542.39
1,235,435.00
511.16
2,248,542.00
9,779.16
195,780.51
263,336.76
234,131.24
2,640,221.52
105,410.84
643,443.60
109,662.90
8,999,804.63

22,573,717
802,019
328
1,366,045
5,087
99,237
113,027
96,237
980,768
36,857
139,707
20,202
625,070

27,719,915
984,858
403
1,677,466
6,247
121,860
138,794
118,176
1,204,357
45,259
171,556
24,808
767,569

9,067,266
337,058
144
728,474
4,217
87,625
142,976
132,344
1,620,680
67,530
516,928
92,532
8,862,222

51,066,601.71

26,858,301

32,981,268

21,659,996

20.86
20.88
20.90
20.98
21.12
21.13
21.20
21.21
21.23
21.24
21.29
21.30
21.32

434,672
16,143
7
34,722
200
4,147
6,744
6,240
76,339
3,179
24,280
4,344
415,676
1,026,693

GHENT UNIT 4
INTERIM SURVIVOR CURVE.. IOWA 100-R2.5
PROBABLE RETIREMENT YEAR.. 6-2038
NET SALVAGE PERCENT.. -7
1984
1985
1986
1987
1988
1989
1990
1991

15,550,093.93
931,420.00
734,905.00
15,869.00
8,118.00
20,054.00
23,192.76
16,217.00

9,669,523
571,382
444,460
9,455
4,758
11,558
13,131
9,013

10,099,433
596,786
464,221
9,875
4,970
12,072
13,715
9,414

6,539,168
399,834
322,128
7,104
3,717
9,386
11,101
7,938

21.86
21.88
21.90
21.92
21.95
21.97
21.99
22.00

299,139
18,274
14,709
324
169
427
505
361

 Attachment to Response to AG-2 Question No. 33(c)
Page 10 of 149
Spanos

GHENT UNIT 4
INTERIM SURVIVOR CURVE.. IOWA 100-R2.5
PROBABLE RETIREMENT YEAR.. 6-2038
NET SALVAGE PERCENT.. -7
1992
1993
1994
1995
1996
1997
2001
2002
2003
2004
2005
2007
2010
2011
2012
2013
2014
2015

24,302.00
42,417.00
11,882.00
28,654.54
80,570.00
1,942,669.00
618,493.64
186,501.00
189,255.91
276,923.25
181,861.63
7,212,117.43
581,597.75
447,887.14
265,809.06
1,076,247.83
2,643,686.56
137,615.33

13,236
22,605
6,188
14,564
39,875
934,481
258,342
74,580
72,029
99,832
61,693
2,108,970
121,854
79,664
38,134
114,882
176,061
3,164

13,824
23,610
6,463
15,212
41,648
976,028
269,828
77,896
75,231
104,271
64,436
2,202,735
127,272
83,206
39,829
119,990
183,889
3,305

12,179
21,776
6,251
15,449
44,562
1,102,628
391,960
121,660
127,272
192,037
130,156
5,514,230
495,038
396,033
244,586
1,031,595
2,644,856
143,944

33,248,360.76

14,973,434

15,639,157

19,936,589

22.02
22.04
22.06
22.07
22.09
22.10
22.16
22.17
22.19
22.20
22.21
22.23
22.26
22.27
22.28
22.29
22.30
22.31

553
988
283
700
2,017
49,893
17,688
5,488
5,736
8,650
5,860
248,054
22,239
17,783
10,978
46,281
118,603
6,452
902,154

GHENT UNIT 2 SCRUBBER
INTERIM SURVIVOR CURVE.. IOWA 100-R2.5
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
1994

15,817,337.72

9,060,051

13,742,096

3,182,455

18.22

15,817,337.72

9,060,051

13,742,096

3,182,455

174,668

321,692,853.29

122,219,463

159,284,854

187,399,801

6,863,997

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 27.3

174,668

2.13

 Attachment to Response to AG-2 Question No. 33(c)
Page 11 of 149
Spanos

TRIMBLE COUNTY UNIT 2 ASH POND
INTERIM SURVIVOR CURVE.. IOWA 100-S4
PROBABLE RETIREMENT YEAR.. 6-2066
NET SALVAGE PERCENT.. 0
1990

4,562,600.30

1,543,893

2,148,119

2,414,481

4,562,600.30

1,543,893

2,148,119

2,414,481

49.86

48,425
48,425

GHENT UNIT 1 SCRUBBER ASH POND
INTERIM SURVIVOR CURVE.. IOWA 100-S4
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. 0
1997

39,480.55

19,740

34,420

5,061

39,480.55

19,740

34,420

5,061

18.50

274
274

GHENT UNIT 1 ASH POND
INTERIM SURVIVOR CURVE.. IOWA 100-S4
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. 0
1987

322,828.55

195,757

304,586

18,243

18.50

322,828.55

195,757

304,586

18,243

986

4,924,909.40

1,759,390

2,487,125

2,437,785

49,685

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 49.1

986

1.01

 Attachment to Response to AG-2 Question No. 33(c)
Page 12 of 149
Spanos

TYRONE UNIT 3
INTERIM SURVIVOR CURVE.. IOWA 100-R2.5
PROBABLE RETIREMENT YEAR.. 12-2015
NET SALVAGE PERCENT.. -10
1947
1948
1949
1951
1953
1954
1955
1966
1970
1973
1978
1994
2003
2006
2007
2009
2013
2015

572,836.03
291,289.73
3,757.35
449.85
284,320.41
19,256.64
1,152.61
18.41
15,244.21
0.48
45,723.00
7,063.50
8,480.22
48,571.39
111,599.81
67,097.35
6,150.84
209,964.73

630,120
320,419
4,133
495
312,752
21,182
1,268
20
16,769
1
50,295
7,770
9,328
53,429
122,760
73,807
6,766
230,961

630,120
320,419
4,133
495
312,752
21,182
1,268
20
16,769
1
50,295
7,770
9,328
53,429
122,760
73,807
6,766
230,961

1,692,976.56

1,862,275

1,862,274

TYRONE UNITS 1 AND 2
INTERIM SURVIVOR CURVE.. IOWA 100-R2.5
PROBABLE RETIREMENT YEAR.. 12-2015
NET SALVAGE PERCENT.. -10
1947
2000
2001
2004

464,339.65
36,257.09
78,101.58
4,683.12

510,774
39,883
85,912
5,151

510,774
39,883
85,912
5,152

583,381.44

641,720

641,720

GREEN RIVER UNIT 3
INTERIM SURVIVOR CURVE.. IOWA 100-R2.5
PROBABLE RETIREMENT YEAR.. 12-2015
NET SALVAGE PERCENT.. -10
1954
1955

1,532,919.98
34,040.75

1,686,212
37,445

1,686,212
37,445

 Attachment to Response to AG-2 Question No. 33(c)
Page 13 of 149
Spanos

GREEN RIVER UNIT 3
INTERIM SURVIVOR CURVE.. IOWA 100-R2.5
PROBABLE RETIREMENT YEAR.. 12-2015
NET SALVAGE PERCENT.. -10
1977
1978
1982
1985
1997
2011

454,212.76
2,303.00
372,934.13
19,443.60
26,427.69
107,003.10

499,634
2,533
410,228
21,388
29,070
117,703

499,634
2,533
410,228
21,388
29,070
117,704

2,549,285.01

2,804,213

2,804,214

GREEN RIVER UNIT 4
INTERIM SURVIVOR CURVE.. IOWA 100-R2.5
PROBABLE RETIREMENT YEAR.. 12-2015
NET SALVAGE PERCENT.. -10
1959
1960
1980
1982
1985
1986
1987
1988
1990
1991
1992
1994
1995
1996
1997
2000
2003
2004
2005
2007
2009
2010

2,136,379.91
9,468.10
37,188.01
1,306.83
14,804.60
78,079.36
8,740.03
18,125.00
0.35
152,430.19
453.00
0.20
238.43
128,584.00
98,050.96
125,696.00
37,909.52
14,553.86
170,827.36
116,707.42
164,177.61
24.08

2,350,018
10,415
40,907
1,438
16,285
85,887
9,614
19,938
167,673
498
262
141,442
107,856
138,266
41,700
16,009
187,910
128,378
180,595
26

2,350,018
10,415
40,907
1,438
16,285
85,887
9,614
19,938
0
167,673
498
0
262
141,442
107,856
138,266
41,700
16,009
187,910
128,378
180,595
26

 Attachment to Response to AG-2 Question No. 33(c)
Page 14 of 149
Spanos

GREEN RIVER UNIT 4
INTERIM SURVIVOR CURVE.. IOWA 100-R2.5
PROBABLE RETIREMENT YEAR.. 12-2015
NET SALVAGE PERCENT.. -10
2011
2012
2013

270,769.12
231,931.02
743,577.10

297,846
255,124
817,935

297,846
255,124
817,935

4,560,022.06

5,016,022

5,016,024

GREEN RIVER UNITS 1 AND 2
INTERIM SURVIVOR CURVE.. IOWA 100-R2.5
PROBABLE RETIREMENT YEAR.. 12-2015
NET SALVAGE PERCENT.. -10
1950
1951
1954
1960
1961
1965
1970
1973
1974
1975
1978
1997

981,876.86
43,895.11
12,435.28
11,239.00
219.00
6,953.70
0.08
5,098.15
28.00
394,531.08
34,073.00
68,189.00

1,080,065
48,285
13,679
12,363
241
7,649
5,608
31
433,984
37,480
75,008

1,080,065
48,285
13,679
12,363
241
7,649
0
5,608
31
433,984
37,480
75,008

1,558,538.26

1,714,393

1,714,392

PINEVILLE UNIT 3
INTERIM SURVIVOR CURVE.. IOWA 100-R2.5
PROBABLE RETIREMENT YEAR.. 12-2015
NET SALVAGE PERCENT.. -10
2013

37,239.96

40,964

40,964

37,239.96

40,964

40,964

10,981,443.29

12,079,587

12,079,588

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 0.0

0.00

 Attachment to Response to AG-2 Question No. 33(c)
Page 15 of 149
Spanos

TRIMBLE COUNTY UNIT 2
INTERIM SURVIVOR CURVE.. IOWA 65-R2
PROBABLE RETIREMENT YEAR.. 6-2066
NET SALVAGE PERCENT.. -11
1990 30,527,801.72
1999
46,214.59
2002
235,262.87
2003
251,881.90
2004
103,726.28
2008
11,126.98
2011 478,940,169.04
2012
4,494,782.01
2013
836,833.81
2014 11,469,287.24
2015
5,016,490.04

12,397,820
13,396
58,010
58,272
22,382
1,659
45,007,253
333,628
45,135
376,326
56,518

19,605,736
21,184
91,736
92,151
35,395
2,624
71,173,828
527,595
71,376
595,117
89,377

14,280,124
30,114
169,406
187,438
79,742
9,727
460,449,759
4,461,613
857,510
12,135,792
5,478,927

531,933,576.48

58,370,399

92,306,117

498,140,153

38.20
41.62
42.58
42.88
43.18
44.26
44.98
45.21
45.43
45.64
45.84

373,825
724
3,979
4,371
1,847
220
10,236,767
98,686
18,875
265,903
119,523
11,124,720

TRIMBLE COUNTY UNIT 2 SCRUBBER
INTERIM SURVIVOR CURVE.. IOWA 65-R2
PROBABLE RETIREMENT YEAR.. 6-2066
NET SALVAGE PERCENT.. -11
1990
2003
2005
2007
2011
2012
2013
2014

11,005,849.25
51,829.65
27,031.69
131,148.15
60,117,074.96
1,218,956.00
131,025.54
338,774.33

4,469,648
11,991
5,401
21,849
5,649,358
90,478
7,067
11,116

8,098,474
21,726
9,786
39,588
10,235,969
163,935
12,805
20,141

4,118,019
35,805
20,219
105,987
56,493,985
1,189,106
132,634
355,899

73,021,689.57

10,266,908

18,602,423

62,451,652

34,124
3,007,150
173,811
11,324
9,905

6,379
597,422
34,923
2,327
2,196

38.20
42.88
43.46
44.00
44.98
45.21
45.43
45.64

107,802
835
465
2,409
1,255,980
26,302
2,920
7,798
1,404,511

BROWN UNIT 1
INTERIM SURVIVOR CURVE.. IOWA 65-R2
PROBABLE RETIREMENT YEAR.. 6-2023
NET SALVAGE PERCENT.. -5
1950
1956
1957
1959
1965

38,574.00
3,432,925.22
198,794.49
13,000.91
11,524.63

35,951
3,168,166
183,118
11,930
10,435

6.64
6.82
6.85
6.90
7.04

961
87,599
5,098
337
312

 Attachment to Response to AG-2 Question No. 33(c)
Page 16 of 149
Spanos

BROWN UNIT 1
INTERIM SURVIVOR CURVE.. IOWA 65-R2
PROBABLE RETIREMENT YEAR.. 6-2023
NET SALVAGE PERCENT.. -5
1966
1968
1973
1974
1975
1977
1978
1983
1984
1985
1987
1988
1989
1990
1991
1992
1994
1995
1996
1997
1999
2001
2002
2003
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015

34.45
1,948.40
1,590,515.65
18,694.00
441,330.00
7,170.50
1,881.00
80,244.00
4,372.00
27,185.00
70,883.58
311,788.04
12,314.44
16,976.00
11,405,119.81
299,803.87
809,175.97
5,085.27
597,835.99
269,896.00
6,580.00
1,316,699.00
13,656.00
217,931.20
1,845,220.71
556,841.17
40,236.58
421,857.31
2,917,291.73
1,903,167.53
2,427,890.91
180,640.37
3,112,190.42
518,642.40
64,953.85
5,005,327.01

31
1,751
1,407,277
16,480
387,673
6,248
1,632
67,933
3,680
22,739
58,507
255,423
10,007
13,682
9,107,393
237,021
625,841
3,884
450,570
200,383
4,720
905,601
9,166
142,274
1,166,228
339,303
23,474
234,121
1,524,318
922,527
1,073,275
70,788
1,035,239
135,180
11,303
330,524

29
1,662
1,335,755
15,642
367,970
5,930
1,549
64,480
3,493
21,583
55,533
242,442
9,498
12,987
8,644,526
224,975
594,034
3,687
427,671
190,199
4,480
859,575
8,700
135,043
1,106,957
322,059
22,281
222,222
1,446,847
875,641
1,018,728
67,190
982,625
128,310
10,729
313,726

7
384
334,287
3,986
95,426
1,599
426
19,776
1,098
6,961
18,894
84,936
3,432
4,838
3,330,850
89,819
255,601
1,653
200,057
93,192
2,429
522,959
5,639
93,785
830,525
262,625
19,967
220,728
1,616,309
1,122,685
1,530,558
122,482
2,285,175
416,265
57,473
4,941,868

40,216,199.41

24,215,796

22,985,071

19,241,938

7.06
7.09
7.17
7.19
7.20
7.23
7.24
7.29
7.30
7.31
7.32
7.33
7.34
7.34
7.35
7.36
7.37
7.38
7.38
7.39
7.40
7.41
7.41
7.41
7.42
7.42
7.43
7.43
7.43
7.44
7.44
7.44
7.44
7.45
7.45
7.45

1
54
46,623
554
13,254
221
59
2,713
150
952
2,581
11,587
468
659
453,177
12,204
34,681
224
27,108
12,611
328
70,575
761
12,657
111,931
35,394
2,687
29,708
217,538
150,899
205,720
16,463
307,147
55,874
7,714
663,338
2,602,922

 Attachment to Response to AG-2 Question No. 33(c)
Page 17 of 149
Spanos

BROWN UNIT 2
INTERIM SURVIVOR CURVE.. IOWA 65-R2
PROBABLE RETIREMENT YEAR.. 6-2029
NET SALVAGE PERCENT.. -5
1963
1964
1965
1966
1975
1976
1977
1978
1980
1985
1988
1989
1990
1991
1992
1993
1994
1995
1996
1998
1999
2002
2003
2004
2005
2007
2008
2009
2010
2011
2012
2013
2014
2015

5,017,723.03
83,935.36
2,757.93
425.52
2,622,355.35
35,297.56
1,845.00
16,079.65
82,061.00
3,930.00
117,057.24
38,963.27
28,392.45
382,847.00
195,307.00
6,201,184.08
58,066.75
314,560.32
64,792.38
380.00
1,985,695.00
30,185.00
419,887.86
3,336,963.09
115,467.62
319,765.64
38,247.48
5,684,731.37
1,991,547.56
636,571.01
6,650,986.04
595,614.98
1,500,354.55
2,879,014.14

4,155,826
69,227
2,265
348
2,045,362
27,360
1,421
12,297
61,826
2,834
81,695
26,854
19,318
256,807
129,077
4,033,845
37,131
197,440
39,854
223
1,137,398
15,720
210,393
1,599,069
52,628
128,644
14,234
1,925,649
601,303
165,964
1,428,482
97,224
156,576
107,194

3,515,320
58,558
1,916
294
1,730,126
23,143
1,202
10,402
52,297
2,397
69,104
22,715
16,341
217,227
109,183
3,412,139
31,408
167,010
33,712
189
962,099
13,297
177,967
1,352,617
44,517
108,817
12,040
1,628,863
508,629
140,385
1,208,321
82,240
132,444
90,673

1,753,289
29,575
980
152
1,023,347
13,919
735
6,482
33,867
1,729
53,806
18,196
13,471
184,762
95,889
3,099,104
29,562
163,278
34,320
210
1,122,880
18,397
262,916
2,151,195
76,724
226,937
28,120
4,340,105
1,582,496
528,014
5,775,214
543,156
1,442,928
2,932,292

41,452,992.23

18,841,488

15,937,592

27,588,050

11.79
11.86
11.92
11.99
12.46
12.50
12.54
12.58
12.66
12.82
12.90
12.93
12.95
12.98
13.00
13.02
13.04
13.06
13.08
13.12
13.13
13.18
13.19
13.21
13.22
13.25
13.26
13.27
13.28
13.29
13.30
13.31
13.32
13.33

148,710
2,494
82
13
82,131
1,114
59
515
2,675
135
4,171
1,407
1,040
14,234
7,376
238,026
2,267
12,502
2,624
16
85,520
1,396
19,933
162,846
5,804
17,127
2,121
327,061
119,164
39,730
434,227
40,808
108,328
219,977
2,105,633

 Attachment to Response to AG-2 Question No. 33(c)
Page 18 of 149
Spanos

BROWN UNIT 3
INTERIM SURVIVOR CURVE.. IOWA 65-R2
PROBABLE RETIREMENT YEAR.. 6-2035
NET SALVAGE PERCENT.. -5
1971 23,810,289.08
1972
227,473.81
1973
121,887.17
1974
23,028.00
1975
413.00
1976
8,346,832.00
1977
300,180.00
1980
328,422.00
1981
831.05
1982
1,751,913.00
1983
208,501.00
1984
583,948.05
1985
116,941.74
1986
6,308.00
1987
1,331,048.28
1988
825,544.36
1990
642,103.72
1991
23,220.54
1992 12,776,750.40
1993
2,346,857.63
1994
3,077,923.00
1995
750,300.20
1997
4,676,406.78
1998
68,370.00
1999
401,832.00
2000
127,001.94
2001
251,033.71
2002
95,234.56
2003
391,655.38
2004
86,283.64
2005
3,019,751.72
2006
3,135,165.45
2007
8,078,544.98
2008
1,093,013.42
2009
245,739.33
2010
1,209,243.62
2011
3,445,815.41
2012 126,967,027.11

17,337,057
164,375
87,414
16,383
291
5,838,868
208,113
221,265
554
1,155,322
135,881
376,146
74,368
3,959
823,774
503,389
379,121
13,472
7,274,737
1,309,550
1,681,031
400,502
2,370,412
33,684
191,849
58,579
111,539
40,562
159,322
33,332
1,100,817
1,069,447
2,553,818
316,434
64,021
277,456
672,208
20,149,286

17,550,961
166,403
88,493
16,585
295
5,910,908
210,681
223,995
561
1,169,576
137,557
380,787
75,286
4,008
833,938
509,600
383,799
13,638
7,364,492
1,325,707
1,701,771
405,443
2,399,658
34,100
194,216
59,302
112,915
41,062
161,288
33,743
1,114,399
1,082,642
2,585,327
320,338
64,811
280,879
680,502
20,397,887

7,449,843
72,444
39,489
7,594
139
2,853,266
104,508
120,848
312
669,932
81,369
232,359
47,503
2,616
563,663
357,222
290,410
10,743
6,051,096
1,138,493
1,530,048
382,372
2,510,569
37,689
227,708
74,050
150,670
58,934
249,950
56,855
2,056,340
2,209,282
5,897,145
827,326
193,215
988,827
2,937,605
112,917,491

16.78
16.89
16.99
17.09
17.18
17.28
17.37
17.61
17.69
17.76
17.84
17.90
17.97
18.03
18.09
18.15
18.26
18.31
18.36
18.41
18.46
18.50
18.59
18.62
18.66
18.70
18.73
18.77
18.80
18.83
18.86
18.89
18.92
18.94
18.97
18.99
19.02
19.04

443,972
4,289
2,324
444
8
165,120
6,017
6,862
18
37,721
4,561
12,981
2,643
145
31,159
19,682
15,904
587
329,580
61,841
82,885
20,669
135,049
2,024
12,203
3,960
8,044
3,140
13,295
3,019
109,032
116,955
311,688
43,681
10,185
52,071
154,448
5,930,540

 Attachment to Response to AG-2 Question No. 33(c)
Page 19 of 149
Spanos

BROWN UNIT 3
INTERIM SURVIVOR CURVE.. IOWA 65-R2
PROBABLE RETIREMENT YEAR.. 6-2035
NET SALVAGE PERCENT.. -5
2013
2014
2015

27,923,468.83
2,079,275.62
94,144,235.91

3,303,151
155,185
2,472,275

3,343,905
157,100
2,502,778

25,975,737
2,026,140
96,348,670

335,039,815.44

73,138,949

74,041,334

277,750,472

19.06
19.08
19.10

1,362,840
106,192
5,044,433
14,672,211

BROWN UNITS 1, 2 AND 3 SCRUBBER
INTERIM SURVIVOR CURVE.. IOWA 65-R2
PROBABLE RETIREMENT YEAR.. 6-2035
NET SALVAGE PERCENT.. -5
1994
5,159,404.89
2010 32,323,114.73
2012
254,234.17
2013 295,455,751.48
2014
815,518.70
2015
551,915.65

2,817,848
7,416,409
40,346
34,950,347
60,865
14,494

4,831,798
12,717,005
69,182
59,929,777
104,366
24,853

585,578
21,222,266
197,764
250,298,762
751,929
554,658

334,559,939.62

45,300,309

77,676,980

273,610,957

18.46
18.99
19.04
19.06
19.08
19.10

31,721
1,117,550
10,387
13,132,149
39,409
29,040
14,360,256

GHENT UNIT 1 SCRUBBER
INTERIM SURVIVOR CURVE.. IOWA 65-R2
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
1997 21,463,096.55
2010
12,043.79
2011
759,148.82
2012 115,925,898.17
2013
152,123.49
2014
67,811.53
2015
452,417.04

11,384,464
2,929
157,893
19,576,105
19,258
5,408
12,727

17,193,704
4,424
238,462
29,565,358
29,085
8,168
19,221

5,771,809
8,463
573,827
94,475,353
133,687
64,391
464,865

138,832,539.39

31,158,784

47,058,422

101,492,395

17.69
18.05
18.07
18.09
18.11
18.13
18.15

326,275
469
31,756
5,222,518
7,382
3,552
25,612
5,617,564

 Attachment to Response to AG-2 Question No. 33(c)
Page 20 of 149
Spanos

GHENT UNIT 1
INTERIM SURVIVOR CURVE.. IOWA 65-R2
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
1958
50,033.00
1974 49,030,601.98
1979
153,844.00
1980
485,218.64
1981
6,294.00
1982
40,874.00
1983
0.16
1984
705.60
1985
3,913.34
1986
20,989.71
1987
190,485.08
1989
84,769.00
1990
63,912.00
1991
310,440.00
1992
354,903.01
1993
90,815.89
1994
610,532.00
1995
8,510,654.34
1996
780,407.52
1998
134,109.00
1999
149,045.50
2000
37,620.04
2001
4,796,617.93
2002
3,272,250.00
2003
1,558,877.17
2004 53,736,563.83
2005
6,533,312.05
2006
2,661,176.28
2007
1,359,443.47
2008
993,616.17
2009
3,419,068.72
2010
4,229,579.47
2011
5,070,156.45
2012 30,045,027.82
2013
1,558,285.23
2014
2,380,884.08
2015 164,542,264.61

40,658
36,090,171
108,503
338,944
4,352
27,963

8,366
12,367,700
44,070
142,628
1,900
12,669

14.49
16.35
16.75
16.82
16.89
16.96

577
756,434
2,631
8,480
112
747

472
2,586
13,691
122,601
52,982
39,307
187,660
210,702
52,893
348,251
4,747,531
424,950
69,190
74,552
18,199
2,236,281
1,464,877
666,866
21,852,737
2,510,969
958,255
454,462
304,247
943,941
1,028,726
1,054,525
5,073,626
197,266
189,869
4,628,623

45,170
40,095,044
120,543
376,556
4,835
31,066
0
524
2,873
15,210
136,206
58,861
43,669
208,484
234,083
58,762
386,896
5,274,358
472,106
76,868
82,825
20,219
2,484,438
1,627,432
740,867
24,277,703
2,789,608
1,064,591
504,893
338,009
1,048,689
1,142,882
1,171,544
5,636,639
219,156
210,938
5,142,254

231
1,314
7,249
67,613
31,841
24,717
123,686
145,663
38,411
266,373
3,832,043
362,930
66,629
76,654
20,035
2,647,943
1,873,875
927,131
33,220,420
4,201,036
1,782,867
949,712
725,160
2,609,715
3,382,768
4,253,523
26,511,541
1,448,209
2,336,607
170,917,969

17.08
17.14
17.20
17.25
17.35
17.40
17.45
17.49
17.53
17.57
17.61
17.65
17.72
17.76
17.79
17.82
17.85
17.88
17.91
17.93
17.96
17.98
18.01
18.03
18.05
18.07
18.09
18.11
18.13
18.15

14
77
421
3,920
1,835
1,421
7,088
8,328
2,191
15,161
217,606
20,563
3,760
4,316
1,126
148,594
104,979
51,853
1,854,853
234,302
99,269
52,820
40,264
144,743
187,411
235,391
1,465,536
79,967
128,881
9,416,968

347,267,291.09

86,541,428

96,144,803

275,431,198

15,302,639

 Attachment to Response to AG-2 Question No. 33(c)
Page 21 of 149
Spanos

GHENT UNIT 2
INTERIM SURVIVOR CURVE.. IOWA 65-R2
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
1977 58,730,215.55
1978
378,364.00
1979
182,288.33
1980
41,332.94
1981
6,292.00
1982
74,950.00
1986
625,102.42
1987
303,212.93
1988
440,286.00
1989
22,395.85
1990
3,078.00
1991
159,055.00
1992
8,980.53
1994
624,766.08
1995
192,226.00
1996
1,317,733.68
1997
1,696,598.00
1998
31,096.00
1999
1,074,948.00
2000
18,464.61
2001
406,215.00
2002
5,238,048.00
2003
281,282.34
2004
48,776.05
2005
2,911,587.84
2006
388,451.69
2007
384,330.33
2008
179,568.29
2009
322,044.12
2010
5,168,023.27
2011
696,400.85
2012 30,284,534.59
2013 23,210,479.70
2014
1,722,539.01
2015 132,392,306.05

42,176,587
269,302
128,564
28,873
4,351
51,276
407,750
195,156
279,385
13,998
1,893
96,148
5,332
356,371
107,230
717,536
899,910
16,043
537,681
8,932
189,386
2,344,899
120,329
19,835
1,119,020
139,876
128,482
54,984
88,910
1,256,975
144,842
5,114,071
2,938,254
137,367
3,724,235

44,740,983
285,676
136,381
30,629
4,616
54,394
432,542
207,022
296,372
14,849
2,008
101,994
5,656
378,039
113,750
761,163
954,626
17,018
570,373
9,475
200,901
2,487,472
127,645
21,041
1,187,058
148,381
136,294
58,327
94,316
1,333,401
153,649
5,425,014
3,116,904
145,719
3,950,674

18,100,348
119,174
58,668
13,598
2,117
25,803
236,318
117,416
174,734
9,114
1,285
68,195
3,953
290,461
91,932
648,812
860,734
16,254
579,822
10,282
233,749
3,117,239
173,327
31,149
1,928,341
267,263
274,940
133,811
250,271
4,196,384
591,500
26,979,438
21,718,309
1,697,398
137,709,094

269,565,973.05

63,823,783

67,704,359

220,731,232

16.60
16.68
16.75
16.82
16.89
16.96
17.20
17.25
17.30
17.35
17.40
17.45
17.49
17.57
17.61
17.65
17.69
17.72
17.76
17.79
17.82
17.85
17.88
17.91
17.93
17.96
17.98
18.01
18.03
18.05
18.07
18.09
18.11
18.13
18.15

1,090,382
7,145
3,503
808
125
1,521
13,739
6,807
10,100
525
74
3,908
226
16,532
5,220
36,760
48,657
917
32,648
578
13,117
174,635
9,694
1,739
107,548
14,881
15,291
7,430
13,881
232,487
32,734
1,491,401
1,199,244
93,624
7,587,278
12,275,159

 Attachment to Response to AG-2 Question No. 33(c)
Page 22 of 149
Spanos

GHENT UNIT 3
INTERIM SURVIVOR CURVE.. IOWA 65-R2
PROBABLE RETIREMENT YEAR.. 6-2037
NET SALVAGE PERCENT.. -7
1981 130,249,859.69
1982
4,323,370.79
1983
175,918.00
1984
9,724,031.69
1985
13,041.58
1986
5,003.81
1987
1,523,545.00
1989
51,742.00
1990
148,350.00
1994
194,871.00
1995
694,601.50
1996
328,272.00
1997
1,620,817.00
1998
206,918.25
1999
5,607,517.20
2000
72,921.99
2002
602,894.00
2003
855,281.04
2004 71,793,078.90
2005
3,708,105.24
2006
1,083,127.40
2007
170,859.09
2008
34,203.02
2009
5,797,862.51
2010
3,722,211.44
2011
2,923,273.40
2012
5,638,318.74
2013
5,171,161.32
2014 165,523,321.40
2015
3,548,130.68

85,517,200
2,805,349
112,745
6,153,452
8,142
3,080
924,026
30,371
85,582
103,501
360,166
165,903
796,396
98,635
2,586,019
32,429
247,014
333,984
26,563,102
1,291,517
352,470
51,385
9,391
1,430,018
805,674
538,062
839,130
570,854
11,450,159
84,852

99,842,747
3,275,291
131,632
7,184,257
9,506
3,596
1,078,816
35,459
99,918
120,839
420,500
193,694
929,806
115,158
3,019,220
37,861
288,393
389,932
31,012,861
1,507,867
411,515
59,993
10,964
1,669,570
940,638
628,196
979,698
666,481
13,368,250
99,066

39,524,603
1,350,715
56,601
3,220,457
4,449
1,758
551,377
19,905
58,816
87,673
322,724
157,557
804,469
106,245
2,980,823
40,165
356,704
525,219
45,805,733
2,459,805
747,432
122,826
25,633
4,534,143
3,042,129
2,499,706
5,053,303
4,866,661
163,741,704
3,697,434

425,512,609.68

144,350,608

168,531,725

286,766,767

19.25
19.34
19.43
19.51
19.59
19.67
19.74
19.89
19.95
20.20
20.25
20.30
20.35
20.40
20.45
20.50
20.58
20.62
20.66
20.70
20.73
20.77
20.80
20.83
20.86
20.89
20.92
20.95
20.98
21.00

2,053,226
69,840
2,913
165,067
227
89
27,932
1,001
2,948
4,340
15,937
7,761
39,532
5,208
145,762
1,959
17,333
25,471
2,217,122
118,831
36,056
5,914
1,232
217,674
145,836
119,660
241,554
232,299
7,804,657
176,068
13,903,449

GHENT UNIT 4
INTERIM SURVIVOR CURVE.. IOWA 65-R2
PROBABLE RETIREMENT YEAR.. 6-2038
NET SALVAGE PERCENT.. -7
1984 124,057,452.69
1986
209,125.43

77,152,000
126,371

71,546,986
117,190

61,194,489
106,574

20.29
20.47

3,015,993
5,206

 Attachment to Response to AG-2 Question No. 33(c)
Page 23 of 149
Spanos

GHENT UNIT 4
INTERIM SURVIVOR CURVE.. IOWA 65-R2
PROBABLE RETIREMENT YEAR.. 6-2038
NET SALVAGE PERCENT.. -7
1987
110,311.00
1989
864,078.80
1990
204,757.59
1991
11,877.00
1992
91,017.00
1994
107,547.90
1995
1,910,485.07
1996
704,727.26
1998
7,924.00
1999
1,429,371.01
2000
42,052.00
2001
373,444.57
2002
813,279.13
2003
2,839,191.12
2004 53,556,449.82
2005
4,307,400.14
2006
125,813.69
2007
728,088.85
2008
413,440.17
2009
8,639,729.77
2010
3,571,815.82
2011
6,389,527.31
2012 50,751,342.00
2013 12,001,376.53
2014 460,019,589.15
2015
1,383,225.41

65,656
497,351
115,761
6,588
49,462
55,879
968,347
347,764
3,684
642,696
18,229
155,483
323,979
1,077,616
19,236,850
1,455,082
39,654
211,825
109,790
2,055,055
745,450
1,132,036
7,253,377
1,273,617
30,552,155
32,339

60,886
461,219
107,351
6,109
45,869
51,819
897,998
322,499
3,416
596,005
16,905
144,187
300,442
999,328
17,839,312
1,349,372
36,773
196,436
101,814
1,905,757
691,294
1,049,795
6,726,427
1,181,090
28,332,572
29,990

57,147
463,345
111,740
6,599
51,520
63,257
1,146,221
431,559
5,062
933,422
28,091
255,398
569,766
2,038,606
39,466,089
3,259,546
97,847
582,619
340,567
7,338,754
3,130,549
5,786,999
47,577,509
11,660,383
463,888,388
1,450,062

735,664,440.23

145,704,096

135,118,842

652,042,109

20.55
20.71
20.78
20.85
20.92
21.05
21.11
21.17
21.28
21.33
21.38
21.43
21.48
21.52
21.57
21.61
21.65
21.69
21.72
21.76
21.79
21.82
21.86
21.89
21.91
21.94

2,781
22,373
5,377
316
2,463
3,005
54,298
20,385
238
43,761
1,314
11,918
26,525
94,731
1,829,675
150,835
4,519
26,861
15,680
337,259
143,669
265,215
2,176,464
532,681
21,172,450
66,092
30,032,084

GHENT UNIT 2 SCRUBBER
INTERIM SURVIVOR CURVE.. IOWA 65-R2
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
1994
2001
2002
2003
2004

55,782,191.35
57,800.67
491,092.43
244,482.98
556,738.99

31,818,513
26,948
219,846
104,586
226,406

56,178,615
47,579
388,159
184,657
399,741

3,508,330
14,267
137,310
76,940
195,969

17.57
17.82
17.85
17.88
17.91

199,677
801
7,692
4,303
10,942

 Attachment to Response to AG-2 Question No. 33(c)
Page 24 of 149
Spanos

GHENT UNIT 2 SCRUBBER
INTERIM SURVIVOR CURVE.. IOWA 65-R2
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
2006
2012
2013

13,411.72
8,815,298.69
297,276.90

4,829
1,488,617
37,633

8,526
2,628,295
66,445

5,824
6,804,075
251,642

66,258,293.73

33,927,378

59,902,017

10,994,357

17.96
18.09
18.11

324
376,124
13,895
613,758

GHENT 3 SCRUBBER
INTERIM SURVIVOR CURVE.. IOWA 65-R2
PROBABLE RETIREMENT YEAR.. 6-2037
NET SALVAGE PERCENT.. -7
2007 110,351,445.96
2011
6,848,600.71
2012
249,577.51
2013
222,658.95
2014
567,246.36
2015
221,002.85

33,187,635
1,260,563
37,144
24,580
39,240
5,285

30,565,215
1,160,956
34,209
22,638
36,139
4,867

87,510,832
6,167,047
232,839
215,607
570,814
231,606

118,460,532.34

34,554,447

31,824,024

94,928,746

20.77
20.89
20.92
20.95
20.98
21.00

4,213,328
295,215
11,130
10,292
27,208
11,029
4,568,202

GHENT 4 SCRUBBER
INTERIM SURVIVOR CURVE.. IOWA 65-R2
PROBABLE RETIREMENT YEAR.. 6-2038
NET SALVAGE PERCENT.. -7
2011
2012
2013
2014

243,442.48
252,238,345.08
784,199.26
435,675.38

43,131
36,049,879
83,221
28,935

92,184
77,049,557
177,869
61,843

168,299
192,845,472
661,225
404,330

253,701,662.20

36,205,166

77,381,453

194,079,326

8,878,216

985,215,162 2,995,249,352

137,461,324

3,711,487,554.46 806,399,539

21.82
21.86
21.89
21.91

7,713
8,821,842
30,207
18,454

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 21.8

3.70

 Attachment to Response to AG-2 Question No. 33(c)
Page 25 of 149
Spanos

TRIMBLE COUNTY UNIT 2 ASH POND
INTERIM SURVIVOR CURVE.. IOWA 100-S4
PROBABLE RETIREMENT YEAR.. 6-2066
NET SALVAGE PERCENT.. 0
2011

4,610,665.23

377,291

676,102

3,934,563

4,610,665.23

377,291

676,102

3,934,563

TYRONE UNIT 3 ASH POND
INTERIM SURVIVOR CURVE.. IOWA 100-S4
PROBABLE RETIREMENT YEAR.. 12-2015
NET SALVAGE PERCENT.. 0
2005
2007
2008
2009

170,126.36
172,621.19
8,648.65
224,059.52

170,126
172,621
8,649
224,060

170,126
172,621
8,649
224,060

575,455.72

575,456

575,456

GREEN RIVER UNIT 3 ASH POND
INTERIM SURVIVOR CURVE.. IOWA 100-S4
PROBABLE RETIREMENT YEAR.. 12-2015
NET SALVAGE PERCENT.. 0
1978
1985
1997
2004
2005
2007
2009
2010
2011
2012

931,932.13
296.57
5,030.40
49,756.95
26,461.24
72,732.11
246,680.85
130,846.99
334,280.60
33,823.14

931,932
297
5,030
49,757
26,461
72,732
246,681
130,847
334,281
33,823

931,932
297
5,030
49,757
26,461
72,732
246,681
130,847
334,281
33,823

1,831,840.98

1,831,841

1,831,841

50.49

77,928
77,928

 Attachment to Response to AG-2 Question No. 33(c)
Page 26 of 149
Spanos

PINEVILLE UNIT 3 ASH POND
INTERIM SURVIVOR CURVE.. IOWA 100-S4
PROBABLE RETIREMENT YEAR.. 12-2015
NET SALVAGE PERCENT.. 0
1977
1978

50,117.00
41,148.89

50,117
41,149

50,117
41,149

91,265.89

91,266

91,266

BROWN UNIT 1 ASH POND
INTERIM SURVIVOR CURVE.. IOWA 100-S4
PROBABLE RETIREMENT YEAR.. 6-2023
NET SALVAGE PERCENT.. 0
1993

9,299,115.00

6,974,336

7,598,416

1,700,699

9,299,115.00

6,974,336

7,598,416

1,700,699

7.50

226,760
226,760

BROWN UNIT 2 ASH POND
INTERIM SURVIVOR CURVE.. IOWA 100-S4
PROBABLE RETIREMENT YEAR.. 6-2029
NET SALVAGE PERCENT.. 0
1994

3,909,061.67

2,401,297

3,256,464

652,598

3,909,061.67

2,401,297

3,256,464

652,598

13.50

48,341
48,341

BROWN UNIT 3 ASH POND
INTERIM SURVIVOR CURVE.. IOWA 100-S4
PROBABLE RETIREMENT YEAR.. 6-2035
NET SALVAGE PERCENT.. 0
2008

19,802,080.26

5,500,622

6,026,115

13,775,965

19,802,080.26

5,500,622

6,026,115

13,775,965

19.50

706,460
706,460

 Attachment to Response to AG-2 Question No. 33(c)
Page 27 of 149
Spanos

GHENT UNIT 1 ASH POND
INTERIM SURVIVOR CURVE.. IOWA 100-S4
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. 0
1974

1,777,792.39

1,230,463

1,464,285

313,507

1,777,792.39

1,230,463

1,464,285

313,507

18.46

16,983
16,983

GHENT UNIT 4 ASH POND
INTERIM SURVIVOR CURVE.. IOWA 100-S4
PROBABLE RETIREMENT YEAR.. 6-2038
NET SALVAGE PERCENT.. 0
1994
2004

16,544,368.68
16,148,295.19

8,084,240
5,461,999

7,960,266
5,378,237

8,584,103
10,770,058

22.50
22.50

381,516
478,669

32,692,663.87

13,546,239

13,338,503

19,354,161

860,185

39,731,493

1,936,657

GHENT UNIT 2 SCRUBBER ASH POND
INTERIM SURVIVOR CURVE.. IOWA 100-S4
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. 0
1994

1,901,133.18

1,021,859

1,901,133

1,901,133.18

1,021,859

1,901,133

76,491,074.19

33,550,670

36,759,581

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 20.5

2.53

 Attachment to Response to AG-2 Question No. 33(c)
Page 28 of 149
Spanos

TYRONE UNIT 3
INTERIM SURVIVOR CURVE.. IOWA 65-R2
PROBABLE RETIREMENT YEAR.. 12-2015
NET SALVAGE PERCENT.. -10
2009
2011

80,855.84
10,306.64

88,941
11,337

88,941
11,338

91,162.48

100,278

100,279

TYRONE UNITS 1 AND 2
INTERIM SURVIVOR CURVE.. IOWA 65-R2
PROBABLE RETIREMENT YEAR.. 12-2015
NET SALVAGE PERCENT.. -10
1973
1974

32,257.44
3,680.00

35,483
4,048

35,483
4,048

35,937.44

39,531

39,531

GREEN RIVER UNIT 3
INTERIM SURVIVOR CURVE.. IOWA 65-R2
PROBABLE RETIREMENT YEAR.. 12-2015
NET SALVAGE PERCENT.. -10
2012
2013

10,061.86
31,239.04

11,068
34,363

11,068
34,363

41,300.90

45,431

45,431

GREEN RIVER UNIT 4
INTERIM SURVIVOR CURVE.. IOWA 65-R2
PROBABLE RETIREMENT YEAR.. 12-2015
NET SALVAGE PERCENT.. -10
1965
1975
1977
1979
1980
1981
1985
1988
2001
2005

0.10
6,388.26
1,272.00
4,376.00
2,331.62
5,272.42
692.53
83,465.37
18,275.84
76,387.85

7,027
1,399
4,814
2,565
5,800
762
91,812
20,103
84,027

0
7,027
1,399
4,814
2,565
5,800
762
91,812
20,103
84,027

 Attachment to Response to AG-2 Question No. 33(c)
Page 29 of 149
Spanos

GREEN RIVER UNIT 4
INTERIM SURVIVOR CURVE.. IOWA 65-R2
PROBABLE RETIREMENT YEAR.. 12-2015
NET SALVAGE PERCENT.. -10
2007
2012
2013

795.41
333,641.83
66,416.30

875
367,006
73,058

875
367,006
73,058

599,315.53

659,248

659,247

GREEN RIVER UNITS 1 AND 2
INTERIM SURVIVOR CURVE.. IOWA 65-R2
PROBABLE RETIREMENT YEAR.. 12-2015
NET SALVAGE PERCENT.. -10
1974
1975
1977

27,465.06
32,966.94
91,811.76

30,212
36,264
100,993

30,212
36,264
100,993

152,243.76

167,469

167,468

PINEVILLE UNIT 3
INTERIM SURVIVOR CURVE.. IOWA 65-R2
PROBABLE RETIREMENT YEAR.. 12-2015
NET SALVAGE PERCENT.. -10
1951
1963
1970
1975
1976
1978
1979
1988
1995
1997

5,844.00
7,129.00
1,082.00
8,772.00
20.00
2,577.11
8,108.00
1,821.00
31,090.00
6,678.00

6,428
7,842
1,190
9,649
22
2,835
8,919
2,003
34,199
7,346

6,428
7,842
1,190
9,649
22
2,835
8,919
2,003
34,199
7,346

 Attachment to Response to AG-2 Question No. 33(c)
Page 30 of 149
Spanos

PINEVILLE UNIT 3
INTERIM SURVIVOR CURVE.. IOWA 65-R2
PROBABLE RETIREMENT YEAR.. 12-2015
NET SALVAGE PERCENT.. -10
2000
2002
2011

10,484.00
51,958.50
9,638.92

11,532
57,154
10,603

11,532
57,154
10,603

145,202.53

159,722

159,723

1,065,162.64

1,171,679

1,171,679

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 0.0

0.00

 Attachment to Response to AG-2 Question No. 33(c)
Page 31 of 149
Spanos

TRIMBLE COUNTY UNIT 2
INTERIM SURVIVOR CURVE.. IOWA 60-R2
PROBABLE RETIREMENT YEAR.. 6-2066
NET SALVAGE PERCENT.. -11
1990
2008
2011
2012
2014
2015

10,495,573.59
10,044,788.71
66,353,243.45
35,891.34
2,395,609.34
581,903.51

4,416,431
1,525,504
6,321,560
2,709
80,013
6,672

7,247,571
2,503,424
10,373,978
4,446
131,305
10,949

4,402,515
8,646,292
63,278,122
35,394
2,527,821
634,964

35.64
43.09
43.99
44.27
44.80
45.05

123,527
200,657
1,438,466
800
56,425
14,095

89,907,009.94

12,352,889

20,271,673

79,525,108

775,494
3,585
1,491
3,581
12,598
7,095
45,834
80,483
290,714

6.60
6.71
6.98
7.26
7.36
7.37
7.39
7.41
7.43

117,499
534
214
493
1,712
963
6,202
10,861
39,127

1,401,667
63,658
234,929
2,035,400

7.44
7.44
7.45
7.45

188,396
8,556
31,534
273,208

1,833,970

BROWN UNIT 1
INTERIM SURVIVOR CURVE.. IOWA 60-R2
PROBABLE RETIREMENT YEAR.. 6-2023
NET SALVAGE PERCENT.. -5
1956
1959
1968
1985
1996
1997
2001
2004
2009
2010
2012
2013
2014
2015

3,283,253.45
14,882.13
5,774.91
11,462.31
32,671.87
17,942.90
103,385.99
163,261.40
467,034.49
0.03
1,851,245.33
77,712.20
262,052.93
2,050,071.73

3,029,003
13,650
5,184
9,584
24,609
13,315
71,104
103,095
226,357
614,593
20,337
45,602
132,835

2,671,922
12,041
4,573
8,454
21,708
11,745
62,722
90,941
199,672
0
542,140
17,940
40,226
117,175

8,340,751.67

4,309,268

3,801,260

4,956,529

4,069,971
26,569
7,712
19,635

148,727
1,216
1,495
5,215

679,299

BROWN UNIT 2
INTERIM SURVIVOR CURVE.. IOWA 60-R2
PROBABLE RETIREMENT YEAR.. 6-2029
NET SALVAGE PERCENT.. -5
1963
1965
1985
1990

4,017,807.85
26,462.00
8,768.76
23,666.17

3,336,822
21,783
6,323
16,098

11.28
11.46
12.67
12.84

13,185
106
118
406

 Attachment to Response to AG-2 Question No. 33(c)
Page 32 of 149
Spanos

BROWN UNIT 2
INTERIM SURVIVOR CURVE.. IOWA 60-R2
PROBABLE RETIREMENT YEAR.. 6-2029
NET SALVAGE PERCENT.. -5
1994
1995
1996
1997
2002
2003
2004
2005
2006
2007
2009
2010
2011
2012
2013
2014
2015

1,497,407.00
574,163.49
32,822.53
33,091.00
1,508,264.00
409,883.72
1,221,923.10
146,394.62
632,295.16
2,547.40
927,175.48
840,714.12
13,859.99
364,931.03
35,612.96
1,106,284.24
317,590.08

957,328
360,228
20,191
19,907
785,155
205,170
585,596
66,726
271,977
1,025
313,887
253,570
3,605
78,287
5,800
115,614
11,842

1,167,667
439,375
24,627
24,281
957,665
250,249
714,260
81,387
331,734
1,250
382,853
309,283
4,397
95,488
7,074
141,016
14,444

404,610
163,496
9,836
10,465
626,012
180,129
568,759
72,328
332,176
1,425
590,682
573,467
10,156
287,690
30,319
1,020,582
319,026

13,741,664.70

7,436,934

9,070,939

5,357,809

6,258,370
11,951
2,187
11,103
4,601
133,545
287,596
6,760,880
187,039
41,879
62,418
35,989
1,957,616
618,620
288,770

766,576
1,568
307
3,037
2,170
67,277
154,999
4,190,400
124,903
30,207
63,642
40,551
2,457,055
872,140
531,358

12.95
12.98
13.00
13.03
13.13
13.15
13.16
13.18
13.20
13.21
13.24
13.25
13.27
13.28
13.29
13.30
13.31

31,244
12,596
757
803
47,678
13,698
43,219
5,488
25,165
108
44,613
43,281
765
21,663
2,281
76,735
23,969
407,878

BROWN UNIT 3
INTERIM SURVIVOR CURVE.. IOWA 60-R2
PROBABLE RETIREMENT YEAR.. 6-2035
NET SALVAGE PERCENT.. -5
1971
1972
1973
1984
1993
1994
1995
1997
1998
1999
2003
2004
2005
2006
2008

6,690,425.21
12,875.38
2,376.00
13,467.21
6,448.62
191,259.00
421,519.00
10,429,790.49
297,088.00
68,653.00
120,057.33
72,895.42
4,204,448.97
1,419,771.42
781,074.49

4,900,884
9,359
1,713
8,695
3,603
104,578
225,214
5,294,396
146,469
32,795
48,879
28,183
1,532,995
484,437
226,134

16.04
16.18
16.32
17.53
18.19
18.25
18.31
18.41
18.46
18.51
18.68
18.72
18.76
18.80
18.86

47,792
97
19
173
119
3,686
8,465
227,615
6,766
1,632
3,407
2,166
130,973
46,390
28,174

 Attachment to Response to AG-2 Question No. 33(c)
Page 33 of 149
Spanos

BROWN UNIT 3
INTERIM SURVIVOR CURVE.. IOWA 60-R2
PROBABLE RETIREMENT YEAR.. 6-2035
NET SALVAGE PERCENT.. -5
2009
2011
2012
2013
2014
2015

810,823.83
407,184.46
16,784,850.43
60,585.16
1,314,686.65
1,347,820.36

211,402
79,673
2,664,058
7,157
97,734
34,758

269,958
101,741
3,401,970
9,139
124,805
44,386

581,407
325,802
14,222,123
54,475
1,255,616
1,370,826

45,458,100.43

16,143,116

20,614,566

27,116,439

18.89
18.95
18.98
19.01
19.03
19.06

30,779
17,193
749,322
2,866
65,981
71,922
1,445,537

GHENT UNIT 1
INTERIM SURVIVOR CURVE.. IOWA 60-R2
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
1974
1975
1976
1979
1980
1985
1989
1992
1994
1995
1996
2001
2002
2003
2004
2006
2008
2009
2011
2012
2013
2014
2015

13,820,013.46
38,921.00
156.00
21,978.00
3,163.50
156,856.25
252,974.07
58,228.11
1,803,234.05
13,200.94
32,637.46
424,030.20
162,462.00
1,132,828.50
1,385,035.03
1,501,464.76
11,574,683.26
426,823.12
3,073,590.83
58,830.81
355,249.66
23,384.79
2,428,504.79

10,214,702
28,528
113
15,541
2,216
103,829
158,271
34,597
1,029,425
7,369
17,784
197,878
72,758
484,766
563,615
540,690
3,543,447
117,902
638,345
9,933
44,915
1,857
67,093

11,887,398
33,200
132
18,086
2,579
120,831
184,188
40,262
1,197,997
8,576
20,696
230,281
84,672
564,148
655,909
629,230
4,123,700
137,209
742,876
11,560
52,270
2,161
78,080

2,900,016
8,446
35
5,431
806
47,005
86,494
22,042
731,463
5,549
14,226
223,431
89,162
647,978
826,078
977,337
8,261,211
319,492
2,545,866
51,389
327,847
22,861
2,520,420

38,748,250.59

17,895,574

20,826,042

20,634,586

15.78
15.90
16.01
16.32
16.41
16.83
17.11
17.29
17.39
17.44
17.49
17.70
17.74
17.78
17.81
17.88
17.94
17.96
18.02
18.04
18.06
18.09
18.11

183,778
531
2
333
49
2,793
5,055
1,275
42,062
318
813
12,623
5,026
36,444
46,383
54,661
460,491
17,789
141,280
2,849
18,153
1,264
139,173
1,173,145

 Attachment to Response to AG-2 Question No. 33(c)
Page 34 of 149
Spanos

GHENT UNIT 2
INTERIM SURVIVOR CURVE.. IOWA 60-R2
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
1977
1978
1979
1980
1981
1985
1993
1996
1997
1998
1999
2002
2004
2005
2006
2009
2011
2012
2013
2014
2015

17,497,877.92
4,313,274.00
20,087.00
2,264.00
899.00
128,384.83
11,440.84
2,506,918.63
29,881.11
64,136.87
678,802.78
137,999.16
951,927.36
458,645.99
172,946.00
2,195,130.77
241,196.39
902,565.37
1,341,650.30
115,704.20
54,523.20

12,605,826
3,079,310
14,204
1,586
623
84,982
6,667
1,366,041
15,858
33,101
339,576
61,803
387,369
176,214
62,279
606,364
50,093
152,395
169,626
9,187
1,506

14,022,022
3,425,254
15,800
1,764
693
94,529
7,416
1,519,508
17,640
36,820
377,726
68,746
430,888
196,011
69,276
674,486
55,721
169,516
188,683
10,219
1,675

4,700,708
1,189,950
5,693
658
269
42,843
4,826
1,162,895
14,333
31,807
348,593
78,913
587,674
294,741
115,777
1,674,304
202,359
796,229
1,246,883
113,584
56,665

31,826,255.72

19,224,610

21,384,390

12,669,704

19,182,251
379,552
23,364
5,543,997
119,245
32,652
1,384,247
1,391
33,690
263,297
424,332

6,462,160
134,064
8,642
2,151,481
48,591
14,684
965,786
1,032
30,637
330,638
585,323

16.12
16.22
16.32
16.41
16.50
16.83
17.34
17.49
17.54
17.58
17.63
17.74
17.81
17.85
17.88
17.96
18.02
18.04
18.06
18.09
18.11

291,607
73,363
349
40
16
2,546
278
66,489
817
1,809
19,773
4,448
32,997
16,512
6,475
93,224
11,230
44,137
69,041
6,279
3,129
744,559

GHENT UNIT 3
INTERIM SURVIVOR CURVE.. IOWA 60-R2
PROBABLE RETIREMENT YEAR.. 6-2037
NET SALVAGE PERCENT.. -7
1981
1982
1983
1984
1985
1987
1995
1996
1999
2003
2004

23,966,739.13
480,015.00
29,912.17
7,192,035.00
156,856.24
44,239.03
2,196,292.70
2,264.00
60,118.00
555,078.69
943,602.66

15,805,420
312,736
19,251
4,568,035
98,253
26,904
1,140,565
1,146
27,759
216,946
349,633

18.70
18.82
18.93
19.04
19.15
19.35
20.01
20.07
20.26
20.47
20.52

345,570
7,123
457
112,998
2,537
759
48,265
51
1,512
16,152
28,525

 Attachment to Response to AG-2 Question No. 33(c)
Page 35 of 149
Spanos

GHENT UNIT 3
INTERIM SURVIVOR CURVE.. IOWA 60-R2
PROBABLE RETIREMENT YEAR.. 6-2037
NET SALVAGE PERCENT.. -7
2005
2006
2007
2009
2011
2012
2013
2014

619,008.50
365,407.85
1,228,187.47
1,824,052.27
1,402,218.14
1,314,528.73
530,602.17
156,580.41

215,783
119,024
369,463
449,739
257,929
195,791
58,750
10,865

261,885
144,454
448,399
545,826
313,036
237,622
71,302
13,186

400,454
246,533
865,762
1,405,910
1,187,338
1,168,924
496,442
154,355

43,067,738.16

24,243,992

29,423,726

16,658,754

28,492,170
160,097
34,231
42,754
75,365
13,118
113,583
183,591
18,385
322
1,562,262
41,874
353,475
478,426
125,126
116,653
382,431
1,936
620,747

15,974,257
93,290
20,774
27,002
51,855
9,877
94,118
159,999
17,844
402
2,447,139
71,588
664,205
998,687
293,294
311,008
1,182,143
8,719
3,607,794

20.57
20.61
20.66
20.74
20.81
20.84
20.88
20.91

19,468
11,962
41,905
67,787
57,056
56,090
23,776
7,382
849,375

GHENT UNIT 4
INTERIM SURVIVOR CURVE.. IOWA 60-R2
PROBABLE RETIREMENT YEAR.. 6-2038
NET SALVAGE PERCENT.. -7
1984
1985
1986
1987
1989
1991
1993
1994
1996
2000
2003
2004
2005
2006
2007
2008
2009
2011
2012

41,557,409.01
236,810.00
51,406.00
65,193.00
118,897.45
21,490.58
194,113.31
321,113.00
33,858.00
676.00
3,747,103.58
106,038.93
951,102.73
1,380,479.45
391,047.02
399,683.45
1,462,218.47
9,957.80
3,951,908.24

25,949,718
145,811
31,176
38,939
68,640
11,947
103,448
167,209
16,744
293
1,422,856
38,137
321,933
435,734
113,961
106,244
348,305
1,763
565,356

19.78
19.89
20.01
20.11
20.32
20.51
20.68
20.76
20.91
21.18
21.36
21.41
21.46
21.51
21.56
21.60
21.65
21.73
21.77

807,596
4,690
1,038
1,343
2,552
482
4,551
7,707
853
19
114,566
3,344
30,951
46,429
13,604
14,399
54,602
401
165,723

 Attachment to Response to AG-2 Question No. 33(c)
Page 36 of 149
Spanos

GHENT UNIT 4
INTERIM SURVIVOR CURVE.. IOWA 60-R2
PROBABLE RETIREMENT YEAR.. 6-2038
NET SALVAGE PERCENT.. -7
2013
2014
2015

766,472.18
2,164,941.54
25,437.69

81,299
144,225
596

89,264
158,356
654

730,861
2,158,132
26,564

21.81
21.84
21.87

57,957,357.43

30,114,334

33,064,819

28,949,553

1,408,391

329,047,128.64

131,720,717

158,457,415

195,868,482

8,542,154

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 22.9

33,510
98,816
1,215

2.60

 Attachment to Response to AG-2 Question No. 33(c)
Page 37 of 149
Spanos

TRIMBLE COUNTY UNIT 2
INTERIM SURVIVOR CURVE.. IOWA 70-R3
PROBABLE RETIREMENT YEAR.. 6-2066
NET SALVAGE PERCENT.. -11
1990
2008
2011
2012
2013
2014
2015

9,229,511.61
28,344.56
35,974,616.47
1,088,194.59
159,449.60
447,854.18
228,635.93

3,816,787
4,270
3,398,598
81,533
8,665
14,923
2,548

4,210,142
4,710
3,748,855
89,936
9,558
16,461
2,811

6,034,616
26,752
36,182,970
1,117,960
167,431
480,657
250,975

47,156,606.94

7,327,324

8,082,472

44,261,362

40.89
47.00
47.62
47.80
47.98
48.14
48.30

147,582
569
759,827
23,388
3,490
9,985
5,196
950,037

TRIMBLE COUNTY UNIT 2 SCRUBBER
INTERIM SURVIVOR CURVE.. IOWA 70-R3
PROBABLE RETIREMENT YEAR.. 6-2066
NET SALVAGE PERCENT.. -11
1990

1,415,469.10

585,355

751,018

820,153

1,415,469.10

585,355

751,018

820,153

1,012,485
100,781
806
65,705
2,178
57,601
1,706
1,205
1,236,797
53,254
506,992
91,232
9,545
23,848

837
493
13
1,392
64
4,097
237
206
262,661
18,493
298,375
83,120
10,494
32,675

40.89

20,058
20,058

BROWN UNIT 1
INTERIM SURVIVOR CURVE.. IOWA 70-R3
PROBABLE RETIREMENT YEAR.. 6-2023
NET SALVAGE PERCENT.. -5
1956
1958
1963
1965
1968
1979
1989
1992
1995
2001
2006
2009
2010
2011

965,068.08
96,451.16
780.00
63,901.00
2,135.00
58,759.52
1,850.00
1,344.04
1,428,056.08
68,330.19
767,016.47
166,049.72
19,084.61
53,830.80

898,168
89,402
715
58,286
1,932
51,097
1,513
1,069
1,097,154
47,241
449,749
80,931
8,467
21,155

6.88
6.95
7.09
7.14
7.19
7.34
7.41
7.43
7.44
7.47
7.48
7.48
7.49
7.49

122
71
2
195
9
558
32
28
35,304
2,476
39,890
11,112
1,401
4,362

 Attachment to Response to AG-2 Question No. 33(c)
Page 38 of 149
Spanos

BROWN UNIT 1
INTERIM SURVIVOR CURVE.. IOWA 70-R3
PROBABLE RETIREMENT YEAR.. 6-2023
NET SALVAGE PERCENT.. -5
2012
2014
2015

19,084.61
79,740.42
433,058.83

6,369
13,970
28,456

7,180
15,748
32,078

12,859
67,979
422,634

4,224,540.53

2,855,674

3,219,138

1,216,630

7.49
7.49
7.49

1,717
9,076
56,426
162,781

BROWN UNIT 2
INTERIM SURVIVOR CURVE.. IOWA 70-R3
PROBABLE RETIREMENT YEAR.. 6-2029
NET SALVAGE PERCENT.. -5
1948
1963
1965
1966
1970
1984
1994
1995
1997
1998
2005
2010
2011
2012
2014

384.00
817,849.45
1,103.00
397.00
793.56
38,251.57
185,597.00
12,605.00
36,014.00
14,507.07
30,977.05
105,240.55
34,981.18
1,109,729.78
20,568.37

341
686,195
917
329
644
28,139
119,767
7,982
21,865
8,601
14,236
31,964
9,177
240,058
2,153

403
825,252
1,103
396
775
33,841
144,038
9,600
26,296
10,344
17,121
38,441
11,037
288,706
2,589

33,490
55
21
59
6,323
50,839
3,636
11,519
4,888
15,405
72,061
25,694
876,511
19,007

2,408,998.58

1,172,368

1,409,941

1,119,508

4,417,560
72,917
17,876
4,247
838
8,817

13

12.04
12.20
12.27
12.52
13.06
13.27
13.29
13.32
13.33
13.40
13.44
13.45
13.45
13.46

2,782
5
2
5
484
3,831
274
865
367
1,150
5,362
1,910
65,168
1,412
83,617

BROWN UNIT 3
INTERIM SURVIVOR CURVE.. IOWA 70-R3
PROBABLE RETIREMENT YEAR.. 6-2035
NET SALVAGE PERCENT.. -5
1972
1973
1974
1984
1985
1988

4,207,199.70
69,444.66
17,025.00
4,045.00
798.00
8,408.74

3,086,063
50,550
12,289
2,639
514
5,193

18.69

1

 Attachment to Response to AG-2 Question No. 33(c)
Page 39 of 149
Spanos

BROWN UNIT 3
INTERIM SURVIVOR CURVE.. IOWA 70-R3
PROBABLE RETIREMENT YEAR.. 6-2035
NET SALVAGE PERCENT.. -5
1989
1990
1991
1997
2003
2004
2005
2007
2010
2011
2012
2013
2014
2015

8,164.40
9,591.76
5,344.58
778,846.00
45,349.90
18,213.04
6,057.20
1,652,556.67
208,220.77
163,301.43
1,510,611.21
14,410.13
100,287.63
131,881.19

4,963
5,733
3,138
399,449
18,637
7,107
2,230
527,496
48,204
32,164
241,569
1,723
7,561
3,480

8,426
9,733
5,328
678,174
31,641
12,066
3,786
895,569
81,840
54,607
410,130
2,925
12,837
5,908

147
338
284
139,614
15,976
7,058
2,574
839,615
136,792
116,859
1,176,012
12,205
92,465
132,567

8,959,757.01

4,460,702

6,735,226

2,672,519

18.74
18.79
18.83
19.05
19.22
19.24
19.26
19.30
19.34
19.36
19.37
19.38
19.39
19.40

8
18
15
7,329
831
367
134
43,503
7,073
6,036
60,713
630
4,769
6,833
138,260

BROWN UNITS 1, 2 AND 3 SCRUBBER
INTERIM SURVIVOR CURVE.. IOWA 70-R3
PROBABLE RETIREMENT YEAR.. 6-2035
NET SALVAGE PERCENT.. -5
2013

29,308,888.08

3,503,658

5,739,630

25,034,702

29,308,888.08

3,503,658

5,739,630

25,034,702

19.38

1,291,780
1,291,780

GHENT UNIT 1 SCRUBBER
INTERIM SURVIVOR CURVE.. IOWA 70-R3
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
1997
2011
2012

3,016,784.27
5,833.85
9,121,453.85

1,617,982
1,221
1,553,004

2,501,892
1,888
2,401,417

726,067
4,354
7,358,539

12,144,071.97

3,172,207

4,905,197

8,088,960

18.11
18.38
18.39

40,092
237
400,138
440,467

 Attachment to Response to AG-2 Question No. 33(c)
Page 40 of 149
Spanos

GHENT UNIT 1
INTERIM SURVIVOR CURVE.. IOWA 70-R3
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
1974
1978
1994
1995
1996
2000
2004
2005
2007
2009
2011
2012
2013
2014
2015

6,397,687.82
869,693.72
911,155.00
70.00
15,852.00
14,398.00
33,927.95
160,601.93
53,989.17
84,877.13
268,831.65
178,069.98
43,107.20
33,762.45
2,659,970.72

4,775,713
627,485
525,500
39
8,727
7,036
13,941
62,293
18,220
23,647
56,270
30,318
5,498
2,705
73,744

6,515,087
856,023
716,894
53
11,905
9,599
19,018
84,981
24,856
32,260
76,764
41,360
7,500
3,690
100,602

330,439
74,549
258,042
22
5,056
5,807
17,284
86,863
32,912
58,559
210,886
149,175
38,624
32,436
2,745,566

11,725,994.72

6,231,136

8,500,593

4,046,221

16.89
17.21
18.02
18.05
18.08
18.19
18.27
18.29
18.32
18.35
18.38
18.39
18.40
18.41
18.42

19,564
4,332
14,320
1
280
319
946
4,749
1,797
3,191
11,474
8,112
2,099
1,762
149,054
222,000

GHENT UNIT 2
INTERIM SURVIVOR CURVE.. IOWA 70-R3
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
1977
1984
1989
1996
1997
2007
2009
2010
2011
2012
2013
2014
2015

9,885,751.20
2,106,460.46
42,801.92
44,978.99
152,868.92
95,312.10
292,925.23
60,449.95
1,111,858.00
34,908.72
66,340.84
81,708.97
326,067.39

7,195,834
1,427,087
27,078
24,762
81,988
32,166
81,611
14,847
232,727
5,944
8,461
6,546
9,040

8,891,124
1,763,299
33,457
30,596
101,304
39,744
100,838
18,345
287,556
7,344
10,454
8,088
11,170

1,686,629
490,614
12,341
17,532
62,266
62,240
212,592
46,337
902,132
30,008
60,530
79,340
337,722

14,302,432.69

9,148,091

11,303,320

4,000,283

17.14
17.59
17.83
18.08
18.11
18.32
18.35
18.36
18.38
18.39
18.40
18.41
18.42

98,403
27,892
692
970
3,438
3,397
11,585
2,524
49,082
1,632
3,290
4,310
18,335
225,550

 Attachment to Response to AG-2 Question No. 33(c)
Page 41 of 149
Spanos

GHENT UNIT 3
INTERIM SURVIVOR CURVE.. IOWA 70-R3
PROBABLE RETIREMENT YEAR.. 6-2037
NET SALVAGE PERCENT.. -7
1976
1981
1982
1984
1987
1988
2000
2007
2012
2013
2014
2015

639,635.42
25,051,490.27
687,842.97
95,821.00
68,793.51
18,279.36
4,296,425.13
51,757.15
72,766.46
10,609.78
2,462,458.14
32,239.52

449,212
16,684,831
452,768
61,497
42,277
11,058
1,933,342
15,740
10,921
1,186
171,817
789

553,032
20,540,969
557,410
75,710
52,048
13,614
2,380,169
19,378
13,445
1,460
211,527
971

131,378
6,264,126
178,582
26,819
21,561
5,945
2,217,006
36,002
64,415
9,892
2,423,303
33,525

33,488,118.71

19,835,438

24,419,733

11,412,554

19.44
19.95
20.03
20.19
20.41
20.47
21.04
21.23
21.33
21.34
21.36
21.37

6,758
313,991
8,916
1,328
1,056
290
105,371
1,696
3,020
464
113,451
1,569
557,910

GHENT UNIT 4
INTERIM SURVIVOR CURVE.. IOWA 70-R3
PROBABLE RETIREMENT YEAR.. 6-2038
NET SALVAGE PERCENT.. -7
1984
1985
1988
1991
1993
1994
2000
2003
2011
2013
2014
2015

21,606,547.09
48,287.00
20,564.21
5,683.09
155,202.00
24,278.82
2,476,120.09
42,697.44
27,699.80
13,232.05
2,829,163.88
216,083.55

13,629,578
30,038
12,206
3,195
83,604
12,776
1,085,665
16,388
4,951
1,421
189,291
5,059

16,312,398
35,951
14,609
3,824
100,060
15,291
1,299,365
19,614
5,926
1,701
226,551
6,055

6,806,607
15,716
7,395
2,257
66,006
10,688
1,350,083
26,072
23,713
12,458
2,800,655
225,155

27,465,559.02

15,074,172

18,041,343

11,346,805

21.04
21.12
21.35
21.54
21.66
21.71
21.98
22.08
22.29
22.32
22.34
22.35

323,508
744
346
105
3,047
492
61,423
1,181
1,064
558
125,365
10,074
527,907

 Attachment to Response to AG-2 Question No. 33(c)
Page 42 of 149
Spanos

GHENT UNIT 2 SCRUBBER
INTERIM SURVIVOR CURVE.. IOWA 70-R3
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
2011
2012
2013

5,833.85
890,617.40
54,747.62

1,221
151,635
6,983

1,381
171,445
7,895

4,862
781,515
50,685

951,198.87

159,839

180,721

837,062

18.38
18.39
18.40

265
42,497
2,755
45,517

GHENT 3 SCRUBBER
INTERIM SURVIVOR CURVE.. IOWA 70-R3
PROBABLE RETIREMENT YEAR.. 6-2037
NET SALVAGE PERCENT.. -7
2007
2011

11,277,366.96
764,631.32

3,429,621
141,860

3,429,052
141,836

8,637,731
676,319

12,041,998.28

3,571,481

3,570,888

9,314,050

21.23
21.31

406,864
31,737
438,601

GHENT 4 SCRUBBER
INTERIM SURVIVOR CURVE.. IOWA 70-R3
PROBABLE RETIREMENT YEAR.. 6-2038
NET SALVAGE PERCENT.. -7
2011
2012

5,833.83
15,142,207.72

1,043
2,187,130

1,124
2,356,755

5,118
13,845,407

22.29
22.30

15,148,041.55

2,188,173

2,357,879

13,850,525

621,100

220,741,676.05

79,285,618

99,217,099

138,021,334

5,725,585

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 24.1

230
620,870

2.59

 Attachment to Response to AG-2 Question No. 33(c)
Page 43 of 149
Spanos

TYRONE UNIT 3
INTERIM SURVIVOR CURVE.. IOWA 70-R3
PROBABLE RETIREMENT YEAR.. 12-2015
NET SALVAGE PERCENT.. -10
2007

24,678.67

27,147

27,147

24,678.67

27,147

27,147

GREEN RIVER UNIT 3
INTERIM SURVIVOR CURVE.. IOWA 70-R3
PROBABLE RETIREMENT YEAR.. 12-2015
NET SALVAGE PERCENT.. -10
1954
1955
1996
2007

17,322.04
443.76
107,389.55
40,561.24

19,054
488
118,129
44,617

19,054
488
118,129
44,617

165,716.59

182,288

182,288

GREEN RIVER UNIT 4
INTERIM SURVIVOR CURVE.. IOWA 70-R3
PROBABLE RETIREMENT YEAR.. 12-2015
NET SALVAGE PERCENT.. -10
1959
1995
2001
2003
2005
2006
2009
2010
2011
2012

16,325.58
26,722.51
33,590.00
17,006.69
60,053.27
19,724.94
79,664.81
90,945.25
91,557.59
44,842.47

17,958
29,395
36,949
18,707
66,059
21,697
87,631
100,040
100,713
49,327

17,958
29,395
36,949
18,707
66,059
21,697
87,631
100,040
100,713
49,326

480,433.11

528,476

528,476

670,828.37

737,911

737,911

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 0.0

0.00

 Attachment to Response to AG-2 Question No. 33(c)
Page 44 of 149
Spanos

TRIMBLE COUNTY UNIT 2
INTERIM SURVIVOR CURVE.. IOWA 75-R1.5
PROBABLE RETIREMENT YEAR.. 6-2066
NET SALVAGE PERCENT.. -11
2000
2002
2011
2012
2013
2014
2015

41,467.41
26,900.64
6,316,703.85
203,432.33
838,229.79
889,231.16
53,544.80

10,738
6,246
564,990
14,425
43,228
27,924
578

11,599
6,747
610,291
15,582
46,694
30,163
624

34,430
23,113
6,401,250
210,228
883,741
956,884
58,810

8,369,509.98

668,129

721,700

8,568,456

134
5,917
27,039
55,415
1,900
20,854
37,231
2,139
1,490
2,516
20,737
28,556
25,908
289
26,511
125,416
218,491
65,120
40,498
8,977
23,490
48,643
16,897
39,799
22,458

98
4,469
21,842
46,399
1,712
19,540
36,341
2,383
1,741
3,093
26,885
39,129
37,697
448
43,946
223,255
420,167
136,097
92,733
22,742
66,551
180,025
74,047
213,503
154,511

43.58
43.93
45.30
45.43
45.56
45.69
45.81

790
526
141,308
4,628
19,397
20,943
1,284
188,876

SYSTEM LABORATORY
INTERIM SURVIVOR CURVE.. IOWA 75-R1.5
PROBABLE RETIREMENT YEAR.. 6-2040
NET SALVAGE PERCENT.. -1
1983
1984
1986
1987
1989
1990
1991
1994
1995
1996
1997
1998
1999
2000
2001
2002
2003
2004
2005
2006
2007
2009
2010
2011
2012

229.68
10,283.72
48,397.00
100,806.00
3,576.00
39,994.08
72,843.39
4,476.87
3,198.74
5,552.69
47,150.16
67,015.37
62,975.53
730.00
69,759.00
345,217.94
632,334.03
199,225.39
131,911.92
31,404.52
89,149.53
226,404.22
90,044.40
250,794.23
175,216.25

129
5,716
26,118
53,528
1,835
20,144
35,963
2,066
1,439
2,430
20,031
27,584
25,026
279
25,608
121,145
211,051
62,903
39,119
8,671
22,690
46,987
16,322
38,444
21,693

22.43
22.49
22.60
22.66
22.76
22.80
22.85
22.98
23.02
23.06
23.10
23.13
23.17
23.20
23.24
23.27
23.30
23.33
23.36
23.39
23.42
23.47
23.50
23.53
23.55

4
199
966
2,048
75
857
1,590
104
76
134
1,164
1,692
1,627
19
1,891
9,594
18,033
5,834
3,970
972
2,842
7,670
3,151
9,074
6,561

 Attachment to Response to AG-2 Question No. 33(c)
Page 45 of 149
Spanos

SYSTEM LABORATORY
INTERIM SURVIVOR CURVE.. IOWA 75-R1.5
PROBABLE RETIREMENT YEAR.. 6-2040
NET SALVAGE PERCENT.. -1
2013
2014
2015

161,221.62
325,883.54
38,318.47

14,758
18,557
771

15,278
19,211
798

147,556
309,931
37,903

3,234,114.29

871,007

901,711

2,364,744

23.58
23.60
23.62

6,258
13,133
1,605
101,143

BROWN UNIT 1
INTERIM SURVIVOR CURVE.. IOWA 75-R1.5
PROBABLE RETIREMENT YEAR.. 6-2023
NET SALVAGE PERCENT.. -5
1954
1955
1956
1958
1971
1980
1988
1990
1992
1994
1995
1996
2001
2003
2005
2007
2011
2014

7,812.22
921.00
150,707.00
497.00
672.26
1,078.00
1,387.17
18,405.00
7,705.00
9,227.37
1,940.96
2,858.88
64,870.51
118,172.07
13,393.06
497.91
8,037.82
37,649.44

7,212
849
138,665
456
597
924
1,133
14,782
6,072
7,111
1,478
2,147
44,472
76,873
8,129
275
3,137
6,529

7,994
941
153,701
505
662
1,024
1,256
16,385
6,730
7,882
1,638
2,380
49,294
85,209
9,010
305
3,477
7,237

209
26
4,541
16
44
108
201
2,940
1,360
1,807
400
622
18,820
38,872
5,052
218
4,963
32,295

445,832.67

320,841

355,631

112,493

BROWN UNIT 2
INTERIM SURVIVOR CURVE.. IOWA 75-R1.5
PROBABLE RETIREMENT YEAR.. 6-2029
NET SALVAGE PERCENT.. -5
1963
1965
1968

59,546.28
541.89
520.36

48,828
441
418

62,524
569
546

7.09
7.10
7.11
7.14
7.26
7.32
7.35
7.36
7.37
7.38
7.38
7.38
7.40
7.40
7.41
7.41
7.42
7.43

29
4
639
2
6
15
27
399
185
245
54
84
2,543
5,253
682
29
669
4,347
15,212

 Attachment to Response to AG-2 Question No. 33(c)
Page 46 of 149
Spanos

BROWN UNIT 2
INTERIM SURVIVOR CURVE.. IOWA 75-R1.5
PROBABLE RETIREMENT YEAR.. 6-2029
NET SALVAGE PERCENT.. -5
1969
1970
1995
1996
1998
2000
2007
2012

4,400.82
555.08
3,998.73
2,858.69
5,685.52
3,709.49
21,010.50
20,279.74

3,517
441
2,491
1,746
3,318
2,050
8,402
4,320

4,621
583
4,199
2,994
5,689
3,515
14,406
7,407

8
281
380
7,655
13,887

123,107.10

75,972

107,051

22,211

3,423
1,979
1,093
50,826
2,392
337,278
14,337
854
2,805
1,754
34,490
1,312
1,334
6,044
738
43,136
8,560
11,719
114,147
169,330
110,786
157,837
241,118
274,771

129
123
73
7,540
373
55,351
2,469
154
533
367
7,577
302
339
1,617
207
12,748
2,662
3,837
39,404
61,614
42,518
63,975
103,358
124,774

13.10
13.12
13.14
13.20
13.24

1
21
29
580
1,049
1,680

BROWN UNIT 3
INTERIM SURVIVOR CURVE.. IOWA 75-R1.5
PROBABLE RETIREMENT YEAR.. 6-2035
NET SALVAGE PERCENT.. -5
1948
1954
1955
1969
1970
1971
1972
1973
1974
1976
1977
1978
1980
1981
1982
1983
1984
1985
1986
1987
1988
1989
1990
1991

3,382.73
2,001.51
1,111.17
55,586.77
2,634.00
373,932.83
16,006.07
960.00
3,179.00
2,020.00
40,063.51
1,537.00
1,594.00
7,296.00
900.00
53,223.00
10,688.00
14,815.00
146,238.43
219,946.00
146,004.06
211,250.31
328,072.94
380,519.00

2,714
1,569
867
40,304
1,897
267,455
11,369
677
2,224
1,391
27,350
1,040
1,058
4,793
585
34,206
6,788
9,293
90,516
134,275
87,851
125,162
191,202
217,888

15.95
16.51
16.60
17.59
17.65
17.71
17.76
17.81
17.86
17.96
18.00
18.05
18.13
18.17
18.21
18.24
18.28
18.31
18.35
18.38
18.41
18.44
18.47
18.50

8
7
4
429
21
3,125
139
9
30
20
421
17
19
89
11
699
146
210
2,147
3,352
2,310
3,469
5,596
6,745

 Attachment to Response to AG-2 Question No. 33(c)
Page 47 of 149
Spanos

BROWN UNIT 3
INTERIM SURVIVOR CURVE.. IOWA 75-R1.5
PROBABLE RETIREMENT YEAR.. 6-2035
NET SALVAGE PERCENT.. -5
1992
1993
1994
1995
1996
1997
1998
1999
2000
2001
2003
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015

143,407.00
213,117.96
244,539.14
406,217.07
132,026.00
247,261.54
28,007.66
78,147.46
12,638.00
61,005.75
217,402.17
87,825.06
126,190.46
93,259.29
109,967.17
76,267.72
25,225.68
510,629.45
184,777.66
256,120.18
319,773.21
312,463.22
471,937.93

80,595
117,448
131,878
214,177
67,927
123,844
13,631
36,869
5,762
26,784
87,467
33,558
45,478
31,453
34,416
21,835
6,492
115,907
35,672
40,247
37,481
23,022
12,230

101,636
148,110
166,307
270,091
85,660
156,175
17,190
46,494
7,266
33,776
110,302
42,319
57,351
39,664
43,401
27,535
8,187
146,166
44,985
50,754
47,266
29,032
15,423

48,942
75,664
90,459
156,437
52,967
103,449
12,218
35,561
6,004
30,280
117,971
49,897
75,149
58,258
72,065
52,546
18,300
389,995
149,032
218,172
288,496
299,054
480,112

6,381,168.11

2,606,647

3,287,152

3,413,075

18.53
18.55
18.58
18.60
18.62
18.65
18.67
18.69
18.71
18.73
18.77
18.79
18.81
18.83
18.84
18.86
18.88
18.89
18.91
18.92
18.94
18.95
18.97

2,641
4,079
4,869
8,411
2,845
5,547
654
1,903
321
1,617
6,285
2,656
3,995
3,094
3,825
2,786
969
20,646
7,881
11,531
15,232
15,781
25,309
181,900

GHENT UNIT 1 SCRUBBER
INTERIM SURVIVOR CURVE.. IOWA 75-R1.5
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
1997
2000
2011

982,956.01
2,454.00
47,617.08

515,606
1,174
9,801

929,086
2,115
17,661

122,677
510
33,290

1,033,027.09

526,581

948,862

156,477

17.74
17.80
17.97

6,915
29
1,853
8,797

 Attachment to Response to AG-2 Question No. 33(c)
Page 48 of 149
Spanos

GHENT UNIT 1
INTERIM SURVIVOR CURVE.. IOWA 75-R1.5
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
1974
1975
1976
1978
1983
1988
1989
1990
1994
1995
1996
1997
1998
1999
2000
2004
2006
2007
2013
2015

1,024,130.37
81,621.12
12,253.24
6,426.72
4,043.88
74,936.00
2,178.22
137,000.67
52,592.00
11,112.00
153,652.05
18,479.01
2,709.00
79,194.16
2,880.81
42,569.91
30,770.07
7,433.84
68,502.65
70,787.92

742,505
58,737
8,748
4,512
2,701
46,969
1,345
83,256
29,643
6,126
82,710
9,693
1,382
39,178
1,378
17,129
10,966
2,460
8,560
1,925

1,066,716
84,384
12,568
6,482
3,880
67,478
1,932
119,609
42,586
8,801
118,825
13,925
1,985
56,285
1,980
24,608
15,754
3,534
12,298
2,766

29,103
2,950
543
394
447
12,704
398
26,981
13,687
3,089
45,583
5,847
913
28,453
1,103
20,942
17,170
4,420
61,000
72,978

1,883,273.64

1,159,923

1,666,398

348,705

17.04
17.08
17.12
17.20
17.38
17.53
17.55
17.58
17.68
17.70
17.72
17.74
17.76
17.78
17.80
17.87
17.90
17.91
18.00
18.03

1,708
173
32
23
26
725
23
1,535
774
175
2,572
330
51
1,600
62
1,172
959
247
3,389
4,048
19,624

GHENT UNIT 2
INTERIM SURVIVOR CURVE.. IOWA 75-R1.5
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
1976
1977
1978
1980
1985
1989
1990
1991
1992
2006

97,461.37
663,118.00
591,177.00
2,018.11
7,576.54
51,128.40
7,692.02
6,857.97
50,988.28
15,073.78

69,583
469,529
415,003
1,390
4,944
31,578
4,674
4,097
29,920
5,372

96,843
653,474
577,587
1,935
6,881
43,949
6,505
5,702
41,642
7,477

7,440
56,062
54,972
225
1,226
10,758
1,725
1,636
12,916
8,652

17.12
17.16
17.20
17.28
17.44
17.55
17.58
17.61
17.63
17.90

435
3,267
3,196
13
70
613
98
93
733
483

 Attachment to Response to AG-2 Question No. 33(c)
Page 49 of 149
Spanos

GHENT UNIT 2
INTERIM SURVIVOR CURVE.. IOWA 75-R1.5
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
2007
2013
2014

7,433.84
17,365.58
9,654.84

2,460
2,170
765

3,424
3,020
1,065

4,530
15,561
9,266

1,527,545.73

1,041,485

1,449,503

184,971

17.91
18.00
18.01

253
864
514
10,632

GHENT UNIT 3
INTERIM SURVIVOR CURVE.. IOWA 75-R1.5
PROBABLE RETIREMENT YEAR.. 6-2037
NET SALVAGE PERCENT.. -7
1981
1982
1983
1984
1987
1988
1993
1994
2004
2007
2013
2014

2,137,927.84
220,596.00
9,393.97
599,875.00
14,126.58
8,279.00
31,841.79
1,429.72
70,857.65
56,110.00
8,682.80
824,923.38

1,379,595
140,702
5,919
373,322
8,429
4,865
17,048
749
25,886
16,665
946
56,729

1,814,698
185,077
7,786
491,062
11,087
6,399
22,425
985
34,050
21,921
1,244
74,620

472,885
50,961
2,266
150,804
4,028
2,459
11,646
545
41,768
38,117
8,046
808,048

3,984,043.73

2,030,855

2,671,355

1,591,572

19.85
19.90
19.95
19.99
20.12
20.15
20.33
20.36
20.62
20.69
20.81
20.82

23,823
2,561
114
7,544
200
122
573
27
2,026
1,842
387
38,811
78,030

GHENT UNIT 4
INTERIM SURVIVOR CURVE.. IOWA 75-R1.5
PROBABLE RETIREMENT YEAR.. 6-2038
NET SALVAGE PERCENT.. -7
1984
1985
1986
1987
1988
1989
1990
1991
1992

1,552,539.66
75,061.39
71,918.00
197,214.00
246,937.00
288,049.17
248,790.00
238,960.87
186,806.00

948,190
45,218
42,699
115,362
142,162
163,069
138,347
130,393
99,893

988,466
47,139
44,513
120,262
148,201
169,996
144,224
135,932
104,136

672,751
33,177
32,440
90,757
116,022
138,217
121,982
119,756
95,746

20.83
20.88
20.93
20.97
21.01
21.05
21.09
21.13
21.17

32,297
1,589
1,550
4,328
5,522
6,566
5,784
5,668
4,523

 Attachment to Response to AG-2 Question No. 33(c)
Page 50 of 149
Spanos

GHENT UNIT 4
INTERIM SURVIVOR CURVE.. IOWA 75-R1.5
PROBABLE RETIREMENT YEAR.. 6-2038
NET SALVAGE PERCENT.. -7
1993
1994
1995
1996
1997
1998
1999
2000
2003
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015

119,556.00
96,245.00
403,518.00
260,103.45
261,371.59
36,015.00
626,250.00
69,931.00
274,884.03
259,074.19
117,203.33
15,073.78
167,940.61
38,302.23
82,463.42
820,549.05
575,117.79
694,925.41
65,548.30
109,379.77
572,254.91

62,591
49,225
201,427
126,395
123,434
16,493
277,322
29,880
102,815
91,801
39,052
4,691
48,301
10,031
19,371
169,118
100,626
98,114
6,897
7,173
13,208

65,250
51,316
209,983
131,764
128,677
17,194
289,102
31,149
107,182
95,700
40,711
4,890
50,353
10,457
20,194
176,302
104,900
102,282
7,190
7,478
13,769

62,675
51,666
221,781
146,547
150,991
21,342
380,986
43,677
186,944
181,509
84,697
11,239
129,344
30,526
68,042
701,686
510,476
641,289
62,947
109,559
598,544

21.20
21.24
21.27
21.31
21.34
21.37
21.40
21.42
21.51
21.53
21.56
21.58
21.60
21.63
21.65
21.67
21.69
21.71
21.73
21.75
21.77

8,771,982.95

3,423,298

3,568,709

5,817,313

271,431

35,753,605.29

12,724,738

15,678,072

22,580,017

877,325

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 25.7

2,956
2,432
10,427
6,877
7,075
999
17,803
2,039
8,691
8,431
3,928
521
5,988
1,411
3,143
32,381
23,535
29,539
2,897
5,037
27,494

2.45

 Attachment to Response to AG-2 Question No. 33(c)
Page 51 of 149
Spanos

TYRONE UNIT 3
INTERIM SURVIVOR CURVE.. IOWA 75-R1.5
PROBABLE RETIREMENT YEAR.. 12-2015
NET SALVAGE PERCENT.. -10
1987
1989
1994
1995
1996
1998
1999
2000
2003
2004
2009

1.57
18,427.65
16,747.71
7,264.00
21.00
6,158.71
1,781.97
10,208.60
1,945.90
2,086.10
9,848.48

2
20,270
18,422
7,990
23
6,775
1,960
11,229
2,140
2,295
10,833

2
20,270
18,422
7,990
23
6,775
1,960
11,229
2,140
2,295
10,833

74,491.69

81,939

81,941

TYRONE UNITS 1 AND 2
INTERIM SURVIVOR CURVE.. IOWA 75-R1.5
PROBABLE RETIREMENT YEAR.. 12-2015
NET SALVAGE PERCENT.. -10
2003

11,541.15

12,695

12,695

11,541.15

12,695

12,695

GREEN RIVER UNIT 4
INTERIM SURVIVOR CURVE.. IOWA 75-R1.5
PROBABLE RETIREMENT YEAR.. 12-2015
NET SALVAGE PERCENT.. -10
1954
1959
1966
1971
1972
1974
1975
1980
1981
1984
1985
1986

1,164.00
8,874.48
2,606.00
881.40
65.10
36.19
1,648.52
5,026.03
66.60
7,645.65
9,431.32
1,692.00

1,280
9,762
2,867
970
72
40
1,813
5,529
73
8,410
10,374
1,861

1,280
9,762
2,867
970
72
40
1,813
5,529
73
8,410
10,374
1,861

 Attachment to Response to AG-2 Question No. 33(c)
Page 52 of 149
Spanos

GREEN RIVER UNIT 4
INTERIM SURVIVOR CURVE.. IOWA 75-R1.5
PROBABLE RETIREMENT YEAR.. 12-2015
NET SALVAGE PERCENT.. -10
1989
1992
1993
1995
1996
1997
1999
2001
2003
2004
2006
2007
2009
2010
2011
2012
2014

156.90
1,883.56
4,681.88
8,509.23
19,905.00
5,058.15
13,769.35
8,714.92
6,243.33
20,681.30
4,095.33
10,188.60
3,399.56
2,889.70
101,643.05
90,178.44
39,055.67

173
2,072
5,150
9,360
21,896
5,564
15,146
9,586
6,868
22,749
4,505
11,207
3,740
3,179
111,807
99,196
42,961

173
2,072
5,150
9,360
21,896
5,564
15,146
9,586
6,868
22,749
4,505
11,207
3,740
3,179
111,807
99,196
42,961

380,191.26

418,210

418,210

GREEN RIVER UNITS 1 AND 2
INTERIM SURVIVOR CURVE.. IOWA 75-R1.5
PROBABLE RETIREMENT YEAR.. 12-2015
NET SALVAGE PERCENT.. -10
1941
1950
1974

632.00
40,301.94
4,755.57

695
44,332
5,231

695
44,332
5,231

45,689.51

50,258

50,258

511,913.61

563,102

563,104

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 0.0

0.00

 Attachment to Response to AG-2 Question No. 33(c)
Page 53 of 149
Spanos

DIX DAM
INTERIM SURVIVOR CURVE.. IOWA 100-R4
PROBABLE RETIREMENT YEAR.. 6-2041
NET SALVAGE PERCENT.. 0
1941

879,311.47

672,928

912,333

33,022-

879,311.47

672,928

912,333

33,022-

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 0.0

0.00

 Attachment to Response to AG-2 Question No. 33(c)
Page 54 of 149
Spanos

DIX DAM
INTERIM SURVIVOR CURVE.. IOWA 90-S2.5
PROBABLE RETIREMENT YEAR.. 6-2041
NET SALVAGE PERCENT.. -3
1941
1967
1988
1990
1991
1992
2005
2007
2009
2010
2012
2013
2014

232,513.54
1,469.92
21,653.46
54,778.00
77,146.00
1,037.00
23,670.29
66,025.06
11,732.37
75,260.09
31,110.92
6,860.35
224,345.64

185,326
1,015
11,679
28,440
39,240
516
7,129
17,037
2,458
13,771
3,871
631
12,848

197,683
1,083
12,458
30,336
41,856
550
7,604
18,173
2,622
14,689
4,129
673
13,705

41,806
431
9,845
26,085
37,604
518
16,776
49,833
9,462
62,829
27,915
6,393
217,371

827,602.64

323,961

345,562

506,869

19.02
23.06
24.90
25.00
25.04
25.08
25.41
25.43
25.45
25.46
25.47
25.48
25.48

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 24.7

2,198
19
395
1,043
1,502
21
660
1,960
372
2,468
1,096
251
8,531
20,516
2.48

 Attachment to Response to AG-2 Question No. 33(c)
Page 55 of 149
Spanos

DIX DAM
INTERIM SURVIVOR CURVE.. IOWA 105-S2.5
PROBABLE RETIREMENT YEAR.. 6-2041
NET SALVAGE PERCENT.. -3
1941
1944
1950
1971
1990
1991
1992
1993
1994
2003
2007
2008
2011
2012
2014
2015

5,868,664.83
862.00
229,388.00
3,719.85
7,354.12
1,200,006.00
370,020.00
16,470.00
10,861.26
136,421.67
1,072,820.18
842,093.55
300,776.20
11,493,426.01
297,790.55
34,972.15

4,602,030
668
173,264
2,461
3,804
607,942
183,449
7,978
5,132
46,295
276,494
197,306
46,501
1,429,229
17,048
693

4,975,220
722
187,314
2,661
4,112
657,241
198,325
8,625
5,548
50,049
298,916
213,306
50,272
1,545,129
18,430
749

1,069,505
166
48,955
1,171
3,462
578,765
182,795
8,339
5,639
90,465
806,089
654,050
259,528
10,293,100
288,294
35,272

21,885,646.37

7,600,294

8,216,620

14,325,596

21.60
21.96
22.64
24.45
25.24
25.27
25.29
25.31
25.33
25.44
25.47
25.47
25.48
25.49
25.49
25.49

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 25.1

49,514
8
2,162
48
137
22,903
7,228
329
223
3,556
31,649
25,679
10,186
403,809
11,310
1,384
570,125
2.61

 Attachment to Response to AG-2 Question No. 33(c)
Page 56 of 149
Spanos

DIX DAM
INTERIM SURVIVOR CURVE.. IOWA 75-R3
PROBABLE RETIREMENT YEAR.. 6-2041
NET SALVAGE PERCENT.. -3
1941
1957
1958
1962
1963
1992
1997
2005
2008
2010
2012
2013
2015

47,034.96
67,525.73
4,342.00
12,808.80
31.46
12,412.14
24,821.62
1,992.81
62,158.95
4,035,403.02
4,177,975.81
5,285,996.18
326,392.84

39,205
50,580
3,229
9,240
23
6,183
10,821
601
14,592
739,934
521,088
486,418
6,512

16,976
21,902
1,398
4,001
10
2,677
4,686
260
6,319
320,405
225,640
210,628
2,820

31,470
47,649
3,074
9,192
22
10,107
20,881
1,792
57,705
3,836,061
4,077,675
5,233,948
333,365

14,058,896.32

1,888,426

817,722

13,662,941

14.18
19.32
19.59
20.60
20.82
24.49
24.76
25.08
25.17
25.21
25.26
25.28
25.31

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 25.2

2,219
2,466
157
446
1
413
843
71
2,293
152,164
161,428
207,039
13,171
542,711
3.86

 Attachment to Response to AG-2 Question No. 33(c)
Page 57 of 149
Spanos

DIX DAM
INTERIM SURVIVOR CURVE.. IOWA 40-L2.5
PROBABLE RETIREMENT YEAR.. 6-2041
NET SALVAGE PERCENT.. -3
1941
1947
1949
1950
1952
1953
1960
1961
1962
1963
1974
1975
1989
2010
2012
2013
2014

54,187.00
10,865.00
290.00
411.49
206.57
772.14
1,738.80
56.97
3,724.00
156.52
3,361.98
4,094.59
5,503.19
486,152.97
401,455.77
341,346.54
7,365.24

46,673
9,076
240
338
168
622
1,339
44
2,828
118
2,382
2,888
3,409
95,070
52,767
33,070
438

40,928
7,959
210
296
147
545
1,174
39
2,480
103
2,089
2,533
2,989
83,368
46,272
29,000
384

14,884
3,232
88
127
65
250
617
20
1,356
58
1,374
1,685
2,679
417,369
367,227
322,587
7,202

1,321,688.77

251,470

220,518

1,140,821

6.55
7.56
7.92
8.11
8.49
8.69
10.09
10.30
10.49
10.69
12.33
12.44
15.01
23.34
23.86
24.08
24.29

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 22.7

2,272
428
11
16
8
29
61
2
129
5
111
135
178
17,882
15,391
13,396
297
50,351
3.81

 Attachment to Response to AG-2 Question No. 33(c)
Page 58 of 149
Spanos

DIX DAM
INTERIM SURVIVOR CURVE.. IOWA 40-S0
PROBABLE RETIREMENT YEAR.. 6-2041
NET SALVAGE PERCENT.. -3
1941
1947
1948
1949
1951
1952
1962
1988
1990
1992
1994
1995
1996
2003
2010
2014

3,020.11
1,160.75
65.00
41.43
59.26
2.05
18,423.86
185,484.40
1,449.67
11,230.37
22,393.40
14,300.79
9,512.12
4,481.37
10,026.50
35,295.66

2,954
1,068
59
37
52
2
14,161
99,592
750
5,582
10,633
6,627
4,289
1,557
1,931
2,187

2,273
822
45
28
40
2
10,896
76,631
577
4,295
8,182
5,099
3,300
1,198
1,486
1,683

838
374
22
14
21

2.02
4.27
4.65
5.03
5.80

415
88
5
3
4

8,080
114,418
916
7,272
14,884
9,631
6,497
3,418
8,841
34,672

10.15
17.76
18.16
18.55
18.93
19.11
19.30
20.55
21.83
22.65

796
6,442
50
392
786
504
337
166
405
1,531

316,946.74

151,481

116,558

209,897

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 17.6

11,924
3.76

 Attachment to Response to AG-2 Question No. 33(c)
Page 59 of 149
Spanos

DIX DAM
INTERIM SURVIVOR CURVE.. IOWA 60-R4
PROBABLE RETIREMENT YEAR.. 6-2041
NET SALVAGE PERCENT.. -3
1941
2009
2015

46,976.13
129,383.46
58,149.54

45,224
27,206
1,155

43,369
26,090
1,108

5,016
107,175
58,786

234,509.13

73,585

70,567

170,977

3.92
25.34
25.44

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 21.9

1,280
4,229
2,311
7,820
3.33

 Attachment to Response to AG-2 Question No. 33(c)
Page 60 of 149
Spanos

BROWN CT GAS PIPELINE
INTERIM SURVIVOR CURVE.. SQUARE
PROBABLE RETIREMENT YEAR.. 6-2031
NET SALVAGE PERCENT.. 0
1994
1995

167,723.31
8,686.00

97,461
4,946

110,904
5,628

56,820
3,058

176,409.31

102,407

116,532

59,877

15.50
15.50

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 15.5

3,666
197
3,863
2.19

 Attachment to Response to AG-2 Question No. 33(c)
Page 61 of 149
Spanos

CANE RUN CC 7
INTERIM SURVIVOR CURVE.. IOWA 50-R2.5
PROBABLE RETIREMENT YEAR.. 6-2055
NET SALVAGE PERCENT.. -10
2015

46,895,473.79

670,089

663,228

50,921,793

46,895,473.79

670,089

663,228

50,921,793

36.48

1,395,882
1,395,882

TRIMBLE COUNTY CT 5
INTERIM SURVIVOR CURVE.. IOWA 50-R2.5
PROBABLE RETIREMENT YEAR.. 6-2032
NET SALVAGE PERCENT.. -7
2002
2004
2006

3,566,217.06
27,551.15
146,463.11

1,716,256
12,091
57,175

1,645,021
11,589
54,802

2,170,831
17,891
101,914

3,740,231.32

1,785,522

1,711,412

2,290,636

15.83
15.92
16.00

137,134
1,124
6,370
144,628

TRIMBLE COUNTY CT 6
INTERIM SURVIVOR CURVE.. IOWA 50-R2.5
PROBABLE RETIREMENT YEAR.. 6-2032
NET SALVAGE PERCENT.. -7
2002
2004

3,564,353.91
24,330.33

1,715,359
10,678

1,636,951
10,190

2,176,908
15,844

3,588,684.24

1,726,037

1,647,141

2,192,751

15.83
15.92

137,518
995
138,513

TRIMBLE COUNTY CT 7
INTERIM SURVIVOR CURVE.. IOWA 50-R2.5
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
2004

3,559,154.97

1,461,357

1,423,558

2,384,738

3,559,154.97

1,461,357

1,423,558

2,384,738

17.73

134,503
134,503

 Attachment to Response to AG-2 Question No. 33(c)
Page 62 of 149
Spanos

TRIMBLE COUNTY CT 8
INTERIM SURVIVOR CURVE.. IOWA 50-R2.5
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
2004

3,548,851.71

1,457,127

1,419,437

2,377,834

3,548,851.71

1,457,127

1,419,437

2,377,834

17.73

134,114
134,114

TRIMBLE COUNTY CT 9
INTERIM SURVIVOR CURVE.. IOWA 50-R2.5
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
2004

3,655,976.41

1,501,111

1,452,931

2,458,964

3,655,976.41

1,501,111

1,452,931

2,458,964

17.73

138,689
138,689

TRIMBLE COUNTY CT 10
INTERIM SURVIVOR CURVE.. IOWA 50-R2.5
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
2004

3,653,029.99

1,499,902

1,451,760

2,456,982

3,653,029.99

1,499,902

1,451,760

2,456,982

17.73

138,578
138,578

BROWN CT 5
INTERIM SURVIVOR CURVE.. IOWA 50-R2.5
PROBABLE RETIREMENT YEAR.. 6-2031
NET SALVAGE PERCENT.. -6
2001
2002
2004
2015

754,032.65
1,116.00
19,933.20
10,818.38

385,882
550
8,981
356

370,518
528
8,623
342

428,757
655
12,506
11,126

785,900.23

395,769

380,011

453,043

14.88
14.92
15.00
15.29

28,814
44
834
728
30,420

 Attachment to Response to AG-2 Question No. 33(c)
Page 63 of 149
Spanos

BROWN CT 6
INTERIM SURVIVOR CURVE.. IOWA 50-R2.5
PROBABLE RETIREMENT YEAR.. 6-2029
NET SALVAGE PERCENT.. -6
1999
2005
2006

133,678.33
38,287.07
20,848.62

77,770
17,694
9,098

72,280
16,445
8,456

69,419
24,139
13,644

192,814.02

104,562

97,181

107,202

12.98
13.17
13.19

5,348
1,833
1,034
8,215

BROWN CT 7
INTERIM SURVIVOR CURVE.. IOWA 50-R2.5
PROBABLE RETIREMENT YEAR.. 6-2029
NET SALVAGE PERCENT.. -6
1999
2002
2005
2006
2015

481,712.77
4,117.50
57,093.08
2,042.62
22,546.10

280,246
2,176
26,384
891
846

259,377
2,014
24,419
825
783

251,238
2,351
36,099
1,341
23,116

567,512.07

310,543

287,418

314,145

12.98
13.08
13.17
13.19
13.35

19,356
180
2,741
102
1,732
24,111

BROWN CT 8
INTERIM SURVIVOR CURVE.. IOWA 50-R2.5
PROBABLE RETIREMENT YEAR.. 6-2025
NET SALVAGE PERCENT.. -6
1994
1995
1997
2001

143,346.95
1,730,556.00
120,183.00
18,569.00

104,938
1,248,430
83,828
11,844

102,769
1,222,627
82,095
11,599

49,179
611,762
45,299
8,084

2,012,654.95

1,449,040

1,419,091

714,323

9.17
9.19
9.23
9.30

5,363
66,568
4,908
869
77,708

BROWN CT 9
INTERIM SURVIVOR CURVE.. IOWA 50-R2.5
PROBABLE RETIREMENT YEAR.. 6-2031
NET SALVAGE PERCENT.. -6
1994
1995
1996
1997

2,477,163.92
512,980.00
438,868.00
1,190,538.00

1,527,424
309,801
259,228
686,461

1,702,000
345,210
288,856
764,920

923,793
198,549
176,344
497,050

14.49
14.56
14.62
14.68

63,754
13,637
12,062
33,859

 Attachment to Response to AG-2 Question No. 33(c)
Page 64 of 149
Spanos

BROWN CT 9
INTERIM SURVIVOR CURVE.. IOWA 50-R2.5
PROBABLE RETIREMENT YEAR.. 6-2031
NET SALVAGE PERCENT.. -6
2001
2012
2013

18,569.00
6,254.64
15,782.48

9,503
1,216
2,316

10,589
1,355
2,581

9,094
5,275
14,149

4,660,156.04

2,795,949

3,115,511

1,824,254

14.88
15.23
15.25

611
346
928
125,197

BROWN CT 10
INTERIM SURVIVOR CURVE.. IOWA 50-R2.5
PROBABLE RETIREMENT YEAR.. 6-2031
NET SALVAGE PERCENT.. -6
1995
1997
2001

1,751,485.20
95,664.00
18,569.00

1,057,765
55,160
9,503

1,133,009
59,084
10,179

723,565
42,320
9,504

1,865,718.20

1,122,428

1,202,272

775,389

14.56
14.68
14.88

49,695
2,883
639
53,217

BROWN CT 11
INTERIM SURVIVOR CURVE.. IOWA 50-R2.5
PROBABLE RETIREMENT YEAR.. 6-2026
NET SALVAGE PERCENT.. -6
1996
1997
1998
2001
2004
2011
2013

1,321,515.93
65,678.00
313,025.00
81,269.00
56,158.33
36,259.52
45,109.35

907,092
44,223
206,533
49,763
30,997
11,497
9,177

870,796
42,453
198,269
47,772
29,757
11,037
8,810

530,011
27,165
133,538
38,373
29,771
27,398
39,006

1,919,015.13

1,259,282

1,208,894

825,262

10.14
10.17
10.19
10.25
10.30
10.38
10.40

52,269
2,671
13,105
3,744
2,890
2,639
3,751
81,069

 Attachment to Response to AG-2 Question No. 33(c)
Page 65 of 149
Spanos

HAEFLING UNITS 1, 2 AND 3
INTERIM SURVIVOR CURVE.. IOWA 50-R2.5
PROBABLE RETIREMENT YEAR.. 6-2020
NET SALVAGE PERCENT.. -10
1994
2000
2013

3,638.00
287,491.35
322.20

3,298
244,280
127

951
70,403
37

3,051
245,838
318

291,451.55

247,705

71,390

249,207

4.43
4.46
4.48

689
55,121
71
55,881

PADDY'S RUN GENERATOR 13
INTERIM SURVIVOR CURVE.. IOWA 50-R2.5
PROBABLE RETIREMENT YEAR.. 6-2031
NET SALVAGE PERCENT.. -6
2001
2002
2013
2015

1,906,444.76
3,883.00
42,179.89
183,795.18

975,637
1,913
6,189
6,049

923,257
1,810
5,857
5,724

1,097,575
2,306
38,854
189,099

14.88
14.92
15.25
15.29

2,136,302.83

989,788

936,648

1,327,833

88,832

83,072,927.45

18,776,211

18,487,883

71,674,356

2,769,557

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 25.9

73,762
155
2,548
12,367

3.33

 Attachment to Response to AG-2 Question No. 33(c)
Page 66 of 149
Spanos

CANE RUN CC 7
INTERIM SURVIVOR CURVE.. IOWA 45-R2.5
PROBABLE RETIREMENT YEAR.. 6-2055
NET SALVAGE PERCENT.. -10
2015 111,535,551.95

1,630,538

1,643,640

121,045,467

111,535,551.95

1,630,538

1,643,640

121,045,467

35.63

3,397,291
3,397,291

CANE RUN GAS PIPELINE
INTERIM SURVIVOR CURVE.. IOWA 45-R2.5
PROBABLE RETIREMENT YEAR.. 6-2055
NET SALVAGE PERCENT.. -10
2015

23,414,526.87

342,297

345,052

25,410,928

23,414,526.87

342,297

345,052

25,410,928

35.63

713,189
713,189

TRIMBLE COUNTY CT 5
INTERIM SURVIVOR CURVE.. IOWA 45-R2.5
PROBABLE RETIREMENT YEAR.. 6-2032
NET SALVAGE PERCENT.. -7
2002
2004

237,747.79
1,836.64

114,730
808

109,380
770

145,010
1,195

239,584.43

115,538

110,150

146,205

15.63
15.76

9,278
76
9,354

TRIMBLE COUNTY CT 6
INTERIM SURVIVOR CURVE.. IOWA 45-R2.5
PROBABLE RETIREMENT YEAR.. 6-2032
NET SALVAGE PERCENT.. -7
2002
2004

237,623.60
1,621.94

114,670
713

109,326
680

144,931
1,056

239,245.54

115,383

110,006

145,987

15.63
15.76

9,273
67
9,340

 Attachment to Response to AG-2 Question No. 33(c)
Page 67 of 149
Spanos

TRIMBLE COUNTY CT GAS PIPELINE
INTERIM SURVIVOR CURVE.. IOWA 45-R2.5
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
2002
2005
2006
2013

4,474,853.28
369,111.16
6,150.29
6,019.92

2,032,498
143,564
2,240
768

2,066,980
146,000
2,278
781

2,721,113
248,949
4,303
5,660

4,856,134.65

2,179,070

2,216,039

2,980,025

17.34
17.58
17.65
18.02

156,927
14,161
244
314
171,646

TRIMBLE COUNTY CT 7
INTERIM SURVIVOR CURVE.. IOWA 45-R2.5
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
2004

578,059.38

238,113

231,910

386,614

578,059.38

238,113

231,910

386,614

17.51

22,080
22,080

TRIMBLE COUNTY CT 8
INTERIM SURVIVOR CURVE.. IOWA 45-R2.5
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
2004

576,385.74

237,424

231,239

385,494

576,385.74

237,424

231,239

385,494

17.51

22,016
22,016

TRIMBLE COUNTY CT 9
INTERIM SURVIVOR CURVE.. IOWA 45-R2.5
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
2004

593,786.01

244,591

236,879

398,472

593,786.01

244,591

236,879

398,472

17.51

22,757
22,757

 Attachment to Response to AG-2 Question No. 33(c)
Page 68 of 149
Spanos

TRIMBLE COUNTY CT 10
INTERIM SURVIVOR CURVE.. IOWA 45-R2.5
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
2004
2007

593,307.31
29,565.29

244,394
9,983

236,962
9,679

397,877
21,955

622,872.60

254,377

246,641

419,833

17.51
17.72

22,723
1,239
23,962

BROWN CT 5
INTERIM SURVIVOR CURVE.. IOWA 45-R2.5
PROBABLE RETIREMENT YEAR.. 6-2031
NET SALVAGE PERCENT.. -6
2001
2002
2010

562,558.04
837.00
232,392.85

288,627
413
64,415

213,466
305
47,641

382,846
582
198,696

795,787.89

353,455

261,412

582,123

14.69
14.75
15.11

26,062
39
13,150
39,251

BROWN CT 6
INTERIM SURVIVOR CURVE.. IOWA 45-R2.5
PROBABLE RETIREMENT YEAR.. 6-2029
NET SALVAGE PERCENT.. -6
1999
2009
2010
2011
2014

89,103.45
20,420.52
232,392.75
64,543.29
553,157.19

51,919
7,016
71,157
17,027
58,717

35,815
4,840
49,086
11,746
40,504

58,635
16,806
197,251
56,670
545,842

959,617.20

205,836

141,990

875,204

34,600
4,897

58,519
17,454

12.82
13.20
13.22
13.25
13.30

4,574
1,273
14,921
4,277
41,041
66,086

BROWN CT 7
INTERIM SURVIVOR CURVE.. IOWA 45-R2.5
PROBABLE RETIREMENT YEAR.. 6-2029
NET SALVAGE PERCENT.. -6
1999
2009

87,848.59
21,086.20

51,188
7,245

12.82
13.20

4,565
1,322

 Attachment to Response to AG-2 Question No. 33(c)
Page 69 of 149
Spanos

BROWN CT 7
INTERIM SURVIVOR CURVE.. IOWA 45-R2.5
PROBABLE RETIREMENT YEAR.. 6-2029
NET SALVAGE PERCENT.. -6
2010
2011
2014

232,392.85
64,543.31
553,157.16

71,157
17,027
58,717

48,098
11,509
39,689

198,238
56,907
546,657

959,028.11

205,334

138,794

877,776

13.22
13.25
13.30

14,995
4,295
41,102
66,279

BROWN CT 8
INTERIM SURVIVOR CURVE.. IOWA 45-R2.5
PROBABLE RETIREMENT YEAR.. 6-2025
NET SALVAGE PERCENT.. -6
1995
1997
2010
2012

2,370.10
1,827.00
232,392.85
26,455.57

1,710
1,274
90,001
7,513

2,049
1,527
107,846
9,003

463
410
138,491
19,040

263,045.52

100,498

120,424

158,404

9.09
9.15
9.38
9.40

51
45
14,764
2,026
16,886

BROWN CT 9
INTERIM SURVIVOR CURVE.. IOWA 45-R2.5
PROBABLE RETIREMENT YEAR.. 6-2031
NET SALVAGE PERCENT.. -6
1994
1995
1996
1997
2010
2012
2013
2014

82,736.81
1,271,203.00
198,281.39
219,834.00
232,392.85
26,455.55
1,019,249.16
105,015.81

51,238
771,147
117,599
127,199
64,415
5,159
149,441
9,805

47,648
717,118
109,360
118,287
59,902
4,798
138,971
9,118

40,053
630,357
100,819
114,737
186,435
23,245
941,433
102,199

3,155,168.57

1,296,003

1,205,201

2,139,278

14.14
14.23
14.32
14.41
15.11
15.17
15.20
15.22

2,833
44,298
7,040
7,962
12,339
1,532
61,936
6,715
144,655

 Attachment to Response to AG-2 Question No. 33(c)
Page 70 of 149
Spanos

BROWN CT 10
INTERIM SURVIVOR CURVE.. IOWA 45-R2.5
PROBABLE RETIREMENT YEAR.. 6-2031
NET SALVAGE PERCENT.. -6
1995
1997
2010
2012

21,944.22
1,653.00
232,392.85
26,455.57

13,312
956
64,415
5,159

11,291
811
54,637
4,376

11,970
941
191,699
23,667

282,445.64

83,842

71,115

228,277

14.23
14.41
15.11
15.17

841
65
12,687
1,560
15,153

BROWN CT 11
INTERIM SURVIVOR CURVE.. IOWA 45-R2.5
PROBABLE RETIREMENT YEAR.. 6-2026
NET SALVAGE PERCENT.. -6
1996
1997
1998
2010
2012

16,452.45
18,693.00
7,567.00
232,392.85
26,455.57

11,302
12,598
4,997
84,355
6,985

8,721
9,721
3,856
65,094
5,390

8,718
10,093
4,165
181,242
22,653

301,560.87

120,237

92,783

226,872

10.02
10.06
10.09
10.35
10.37

870
1,003
413
17,511
2,184
21,981

BROWN CT GAS PIPELINE
INTERIM SURVIVOR CURVE.. IOWA 45-R2.5
PROBABLE RETIREMENT YEAR.. 6-2031
NET SALVAGE PERCENT.. -6
1994
1998
1999
2003
2013
2015

7,687,474.69
206.00
381,882.00
36,567.97
68,291.83
33,700.20

4,760,810
116
209,182
17,310
10,013
1,112

5,005,780
122
219,946
18,201
10,528
1,169

3,142,943
96
184,849
20,561
61,861
34,553

8,208,122.69

4,998,543

5,255,746

3,444,864

14.14
14.49
14.56
14.81
15.20
15.25

222,273
7
12,696
1,388
4,070
2,266
242,700

 Attachment to Response to AG-2 Question No. 33(c)
Page 71 of 149
Spanos

HAEFLING UNITS 1, 2 AND 3
INTERIM SURVIVOR CURVE.. IOWA 45-R2.5
PROBABLE RETIREMENT YEAR.. 6-2020
NET SALVAGE PERCENT.. -10
1970
1971
1973
1977
2011

29,175.92
25,248.00
245.00
66,536.25
350,911.66

29,040
25,077
242
65,141
192,353

17,904
15,461
149
40,162
118,594

14,189
12,312
120
33,028
267,409

472,116.83

311,853

192,271

327,058

3.95
3.99
4.06
4.18
4.48

3,592
3,086
30
7,901
59,690
74,299

PADDY'S RUN GENERATOR 13
INTERIM SURVIVOR CURVE.. IOWA 45-R2.5
PROBABLE RETIREMENT YEAR.. 6-2031
NET SALVAGE PERCENT.. -6
2001
2002
2005
2014

1,971,446.95
4,531.00
19,123.07
1,990.13

1,011,473
2,238
8,186
186

965,131
2,135
7,811
177

1,124,603
2,667
12,460
1,932

14.69
14.75
14.91
15.22

1,997,091.15

1,022,083

975,255

1,141,662

77,700

160,050,131.64

14,055,015

13,826,547

161,320,543

5,156,625

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 31.3

76,556
181
836
127

3.22

 Attachment to Response to AG-2 Question No. 33(c)
Page 72 of 149
Spanos

CANE RUN CC 7
INTERIM SURVIVOR CURVE.. IOWA 35-R1.5
PROBABLE RETIREMENT YEAR.. 6-2055
NET SALVAGE PERCENT.. -10
2015

89,873,336.88

1,325,722

1,353,524

97,507,147

89,873,336.88

1,325,722

1,353,524

97,507,147

30.91

3,154,550
3,154,550

TRIMBLE COUNTY CT 5
INTERIM SURVIVOR CURVE.. IOWA 35-R1.5
PROBABLE RETIREMENT YEAR.. 6-2032
NET SALVAGE PERCENT.. -7
2002
2004
2006
2007
2010
2011
2012
2013
2014

28,175,412.09
535,878.89
139,712.62
41,824.49
35,842.85
504,489.32
3,518,543.10
20,239.38
84,338.50

13,329,500
230,893
53,454
14,898
9,369
113,143
643,374
2,786
7,329

12,202,878
211,378
48,936
13,639
8,577
103,580
588,995
2,551
6,710

17,944,813
362,013
100,556
31,113
29,775
436,224
3,175,846
19,106
83,533

33,056,281.24

14,404,746

13,187,243

22,182,978

14.51
14.73
14.93
15.01
15.25
15.31
15.38
15.44
15.50

1,236,720
24,577
6,735
2,073
1,952
28,493
206,492
1,237
5,389
1,513,668

TRIMBLE COUNTY CT 6
INTERIM SURVIVOR CURVE.. IOWA 35-R1.5
PROBABLE RETIREMENT YEAR.. 6-2032
NET SALVAGE PERCENT.. -7
2002
2004
2007
2009
2010
2011
2012
2013
2014

28,160,141.31
615,389.01
9,593.87
15,420.35
17,172.22
3,199,061.90
823,396.88
20,239.38
84,314.06

13,322,276
265,151
3,417
4,564
4,489
717,460
150,560
2,786
7,326

12,447,622
247,743
3,193
4,264
4,194
670,356
140,675
2,603
6,845

17,683,729
410,723
7,073
12,235
14,180
2,752,640
740,359
19,053
83,371

32,944,728.98

14,478,029

13,527,496

21,723,364

14.51
14.73
15.01
15.17
15.25
15.31
15.38
15.44
15.50

1,218,727
27,883
471
807
930
179,794
48,138
1,234
5,379
1,483,363

 Attachment to Response to AG-2 Question No. 33(c)
Page 73 of 149
Spanos

TRIMBLE COUNTY CT 7
INTERIM SURVIVOR CURVE.. IOWA 35-R1.5
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
2004
2006
2007
2011
2012
2013
2014

20,965,127.62
404,108.42
4,356.44
447,639.13
3,194,626.52
1,199,885.22
74,826.31

8,469,461
143,958
1,440
91,819
531,880
149,803
5,870

7,796,350
132,517
1,326
84,522
489,609
137,897
5,403

14,636,336
299,879
3,336
394,452
2,928,642
1,145,980
74,661

26,290,569.66

9,394,231

8,647,624

19,483,286

16.19
16.45
16.56
16.95
17.04
17.11
17.19

904,036
18,230
201
23,272
171,869
66,977
4,343
1,188,928

TRIMBLE COUNTY CT 8
INTERIM SURVIVOR CURVE.. IOWA 35-R1.5
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
2004
2006
2007
2010
2011
2012
2013
2014

20,718,538.04
294,116.88
4,356.44
17,172.20
447,639.11
3,146,258.75
257,690.19
272,690.21

8,369,844
104,775
1,440
4,124
91,819
523,827
32,172
21,393

7,408,812
92,745
1,275
3,650
81,276
463,681
28,478
18,937

14,760,023
221,960
3,387
14,724
397,698
2,902,816
247,251
272,842

25,158,461.82

9,149,394

8,098,854

18,820,700

16.19
16.45
16.56
16.86
16.95
17.04
17.11
17.19

911,675
13,493
205
873
23,463
170,353
14,451
15,872
1,150,385

TRIMBLE COUNTY CT 9
INTERIM SURVIVOR CURVE.. IOWA 35-R1.5
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
2004
2006
2007
2009
2010
2011

20,776,437.14
294,378.88
4,356.44
193,712.50
17,172.22
447,639.11

8,393,234
104,868
1,440
52,786
4,124
91,819

7,701,968
96,231
1,321
48,439
3,784
84,257

14,528,820
218,754
3,340
158,834
14,590
394,717

16.19
16.45
16.56
16.77
16.86
16.95

897,395
13,298
202
9,471
865
23,287

 Attachment to Response to AG-2 Question No. 33(c)
Page 74 of 149
Spanos

TRIMBLE COUNTY CT 9
INTERIM SURVIVOR CURVE.. IOWA 35-R1.5
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
2012
2013
2014

3,063,709.10
17,078.50
74,826.36

510,083
2,132
5,870

468,073
1,956
5,387

2,810,096
16,318
74,678

24,889,310.25

9,166,356

8,411,416

18,220,146

17.04
17.11
17.19

164,912
954
4,344
1,114,728

TRIMBLE COUNTY CT 10
INTERIM SURVIVOR CURVE.. IOWA 35-R1.5
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
2004
2006
2007
2009
2011
2012
2013
2014

20,640,467.03
294,703.99
170,474.64
15,420.35
447,639.11
730,619.77
2,340,915.97
99,584.57

8,338,305
104,984
56,337
4,202
91,819
121,642
292,258
7,813

7,661,757
96,466
51,766
3,861
84,369
111,772
268,545
7,179

14,423,543
218,867
130,642
12,639
394,605
669,991
2,236,235
99,376

24,739,825.43

9,017,360

8,285,715

18,185,898

16.19
16.45
16.56
16.77
16.95
17.04
17.11
17.19

890,892
13,305
7,889
754
23,281
39,319
130,698
5,781
1,111,919

BROWN CT 5
INTERIM SURVIVOR CURVE.. IOWA 35-R1.5
PROBABLE RETIREMENT YEAR.. 6-2031
NET SALVAGE PERCENT.. -6
2001
2002
2003
2006
2007
2010
2011
2012

12,135,401.29
16,181.00
122,530.71
718,680.00
23,148.35
16,889.40
1,590,074.69
99,764.48

6,102,842
7,828
56,778
283,055
8,499
4,584
370,721
19,037

6,035,129
7,741
56,148
279,914
8,405
4,533
366,608
18,826

6,828,396
9,411
73,735
481,886
16,133
13,370
1,318,871
86,925

14,722,669.92

6,853,344

6,777,304

8,828,726

13.67
13.78
13.88
14.14
14.21
14.41
14.47
14.53

499,517
683
5,312
34,080
1,135
928
91,145
5,982
638,782

 Attachment to Response to AG-2 Question No. 33(c)
Page 75 of 149
Spanos

BROWN CT 6
INTERIM SURVIVOR CURVE.. IOWA 35-R1.5
PROBABLE RETIREMENT YEAR.. 6-2029
NET SALVAGE PERCENT.. -6
1999
2002
2006
2007
2008
2009
2010
2012
2013
2014

23,268,758.67
704,287.00
3,762,739.34
28,730.96
6,186,526.42
154,832.01
116,152.53
348,120.25
70,233.07
62,091.32

13,304,485
365,172
1,610,997
11,500
2,288,578
52,112
34,810
74,215
11,359
6,462

10,642,759
292,115
1,288,697
9,199
1,830,720
41,686
27,846
59,367
9,086
5,169

14,022,125
454,429
2,699,807
21,256
4,726,998
122,436
95,276
309,640
65,361
60,648

34,702,471.57

17,759,690

14,206,645

22,577,975

11.98
12.24
12.50
12.56
12.61
12.66
12.71
12.79
12.83
12.86

1,170,461
37,127
215,985
1,692
374,861
9,671
7,496
24,210
5,094
4,716
1,851,313

BROWN CT 7
INTERIM SURVIVOR CURVE.. IOWA 35-R1.5
PROBABLE RETIREMENT YEAR.. 6-2029
NET SALVAGE PERCENT.. -6
1999
2001
2003
2004
2006
2007
2009
2012
2013

18,883,386.83
5,754,196.00
143,366.38
35,835.80
3,472,462.75
28,730.96
3,254,978.30
198,456.45
105,173.75

10,797,041
3,091,749
71,472
17,085
1,486,716
11,500
1,095,532
42,308
17,010

8,840,161
2,531,394
58,518
13,988
1,217,260
9,416
896,975
34,640
13,927

11,176,229
3,568,054
93,450
23,997
2,463,550
21,039
2,553,302
175,724
97,557

31,876,587.22

16,630,413

13,616,280

20,172,902

11.98
12.16
12.31
12.38
12.50
12.56
12.66
12.79
12.83

932,907
293,425
7,591
1,938
197,084
1,675
201,683
13,739
7,604
1,657,646

BROWN CT 8
INTERIM SURVIVOR CURVE.. IOWA 35-R1.5
PROBABLE RETIREMENT YEAR.. 6-2025
NET SALVAGE PERCENT.. -6
1995
1997
1998
2006
2007

13,002,726.13
989,546.00
2,617,425.00
1,654,779.20
7,728,711.57

9,225,715
678,441
1,761,262
859,212
3,787,854

8,296,918
610,139
1,583,947
772,711
3,406,512

5,485,972
438,780
1,190,523
981,355
4,785,922

8.60
8.71
8.75
9.04
9.07

637,904
50,377
136,060
108,557
527,665

 Attachment to Response to AG-2 Question No. 33(c)
Page 76 of 149
Spanos

BROWN CT 8
INTERIM SURVIVOR CURVE.. IOWA 35-R1.5
PROBABLE RETIREMENT YEAR.. 6-2025
NET SALVAGE PERCENT.. -6
2010
2011
2012
2013

20,578.26
483,972.65
43,169.43
139,017.01

7,847
161,922
12,082
30,110

7,057
145,621
10,866
27,079

14,756
367,390
34,894
120,279

26,679,925.25

16,524,445

14,860,849

13,419,872

9.13
9.15
9.17
9.19

1,616
40,152
3,805
13,088
1,519,224

BROWN CT 9
INTERIM SURVIVOR CURVE.. IOWA 35-R1.5
PROBABLE RETIREMENT YEAR.. 6-2031
NET SALVAGE PERCENT.. -6
1994
1995
1996
1997
1998
2006
2008
2009
2012
2013
2014

13,156,279.09
409,078.00
472,854.00
1,221,475.00
2,439,970.00
1,051,911.47
1,524,046.02
637,647.85
43,169.43
7,591,117.33
164,063.77

8,042,041
244,659
276,115
695,638
1,352,102
414,299
515,389
195,269
8,238
1,092,243
14,991

7,607,149
231,429
261,183
658,020
1,278,984
391,895
487,518
184,709
7,793
1,033,177
14,180

6,338,506
202,194
240,042
636,744
1,307,384
723,131
1,127,971
491,197
37,967
7,013,407
159,727

28,711,611.96

12,850,984

12,156,038

18,278,271

12.70
12.86
13.02
13.16
13.30
14.14
14.28
14.35
14.53
14.58
14.63

499,095
15,723
18,436
48,385
98,300
51,141
78,990
34,230
2,613
481,029
10,918
1,338,860

BROWN CT 10
INTERIM SURVIVOR CURVE.. IOWA 35-R1.5
PROBABLE RETIREMENT YEAR.. 6-2031
NET SALVAGE PERCENT.. -6
1995
1996
1997
1999
2006
2010

12,529,955.77
3,189,002.00
61,215.88
66,608.00
1,075,401.49
831,538.26

7,493,831
1,862,163
34,863
35,833
423,551
225,708

7,292,938
1,812,242
33,928
34,872
412,197
219,657

5,988,815
1,568,100
30,960
35,732
727,729
661,773

12.86
13.02
13.16
13.43
14.14
14.41

465,693
120,438
2,353
2,661
51,466
45,925

 Attachment to Response to AG-2 Question No. 33(c)
Page 77 of 149
Spanos

BROWN CT 10
INTERIM SURVIVOR CURVE.. IOWA 35-R1.5
PROBABLE RETIREMENT YEAR.. 6-2031
NET SALVAGE PERCENT.. -6
2012
2014
2015

43,169.43
70,820.51
8,059,176.08

8,238
6,471
259,528

8,017
6,298
252,571

37,742
68,772
8,290,156

25,926,887.42

10,350,186

10,072,720

17,409,781

14.53
14.63
14.68

2,598
4,701
564,725
1,260,560

BROWN CT 11
INTERIM SURVIVOR CURVE.. IOWA 35-R1.5
PROBABLE RETIREMENT YEAR.. 6-2026
NET SALVAGE PERCENT.. -6
1996
1997
1998
1999
2000
2002
2003
2004
2007
2012

14,143,515.81
744,351.00
580,337.00
2,301,040.00
14,259,988.00
336,087.00
1,267,900.75
26,608.61
979,775.63
43,169.43

9,545,187
493,014
376,427
1,458,778
8,819,643
195,989
714,605
14,424
454,807
11,226

9,100,258
470,033
358,881
1,390,780
8,408,534
186,853
681,295
13,752
433,607
10,703

5,891,869
318,979
256,277
1,048,322
6,707,053
169,399
662,680
14,453
604,955
35,057

34,682,773.23

22,084,100

21,054,696

15,709,044

9.45
9.51
9.57
9.63
9.68
9.78
9.82
9.86
9.96
10.09

623,478
33,541
26,779
108,860
692,877
17,321
67,483
1,466
60,738
3,474
1,636,017

PADDY'S RUN GENERATOR 13
INTERIM SURVIVOR CURVE.. IOWA 35-R1.5
PROBABLE RETIREMENT YEAR.. 6-2031
NET SALVAGE PERCENT.. -6
2001
2002
2005
2007
2009

13,635,667.06
37,538.00
23,907.18
40,130.09
1,637,901.07

6,857,320
18,161
10,010
14,734
501,581

4,733,997
12,538
6,910
10,172
346,270

9,719,810
27,253
18,431
32,366
1,389,905

13.67
13.78
14.06
14.21
14.35

711,032
1,978
1,311
2,278
96,857

 Attachment to Response to AG-2 Question No. 33(c)
Page 78 of 149
Spanos

PADDY'S RUN GENERATOR 13
INTERIM SURVIVOR CURVE.. IOWA 35-R1.5
PROBABLE RETIREMENT YEAR.. 6-2031
NET SALVAGE PERCENT.. -6
2012
2013
2014

4,027,492.40
42,179.90
114,061.15

768,531
6,069
10,422

530,561
4,190
7,195

3,738,581
40,521
113,710

14.53
14.58
14.63

19,558,876.85

8,186,828

5,651,832

15,080,577

1,081,308

473,814,317.68

178,175,828

159,908,236

347,600,667

21,701,251

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 16.0

257,301
2,779
7,772

4.58

 Attachment to Response to AG-2 Question No. 33(c)
Page 79 of 149
Spanos

CANE RUN CC 7
INTERIM SURVIVOR CURVE.. IOWA 55-S2.5
PROBABLE RETIREMENT YEAR.. 6-2055
NET SALVAGE PERCENT.. -10
2015 113,390,206.33

1,612,749

1,903,560

122,825,667

113,390,206.33

1,612,749

1,903,560

122,825,667

38.16

3,218,702
3,218,702

TRIMBLE COUNTY CT 5
INTERIM SURVIVOR CURVE.. IOWA 55-S2.5
PROBABLE RETIREMENT YEAR.. 6-2032
NET SALVAGE PERCENT.. -7
2002
2004
2012

3,734,423.83
28,850.68
37,125.91

1,812,270
12,759
6,962

1,673,522
11,782
6,429

2,322,312
19,088
33,296

3,800,400.42

1,831,991

1,691,733

2,374,695

16.23
16.31
16.47

143,088
1,170
2,022
146,280

TRIMBLE COUNTY CT 6
INTERIM SURVIVOR CURVE.. IOWA 55-S2.5
PROBABLE RETIREMENT YEAR.. 6-2032
NET SALVAGE PERCENT.. -7
2002
2004
2012

3,732,468.71
25,477.86
37,125.91

1,811,322
11,267
6,962

1,672,704
10,405
6,429

2,321,037
16,857
33,296

3,795,072.48

1,829,551

1,689,538

2,371,190

16.23
16.31
16.47

143,009
1,034
2,022
146,065

TRIMBLE COUNTY CT 7
INTERIM SURVIVOR CURVE.. IOWA 55-S2.5
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
2004
2012

2,950,282.37
32,943.60

1,220,199
5,623

1,149,660
5,298

2,007,142
29,952

2,983,225.97

1,225,822

1,154,958

2,037,094

18.22
18.44

110,161
1,624
111,785

 Attachment to Response to AG-2 Question No. 33(c)
Page 80 of 149
Spanos

TRIMBLE COUNTY CT 8
INTERIM SURVIVOR CURVE.. IOWA 55-S2.5
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
2004
2012

2,937,930.22
32,943.58

1,215,090
5,623

1,144,837
5,298

1,998,748
29,952

2,970,873.80

1,220,713

1,150,135

2,028,700

18.22
18.44

109,701
1,624
111,325

TRIMBLE COUNTY CT 9
INTERIM SURVIVOR CURVE.. IOWA 55-S2.5
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
2004
2012

2,957,520.12
32,943.58

1,223,192
5,623

1,144,963
5,263

2,019,584
29,986

2,990,463.70

1,228,815

1,150,226

2,049,570

18.22
18.44

110,844
1,626
112,470

TRIMBLE COUNTY CT 10
INTERIM SURVIVOR CURVE.. IOWA 55-S2.5
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
2004
2012

2,954,148.53
32,943.60

1,221,798
5,623

1,143,822
5,264

2,017,117
29,986

2,987,092.13

1,227,421

1,149,086

2,047,103

18.22
18.44

110,709
1,626
112,335

BROWN CT 5
INTERIM SURVIVOR CURVE.. IOWA 55-S2.5
PROBABLE RETIREMENT YEAR.. 6-2031
NET SALVAGE PERCENT.. -6
2001
2002
2011
2012

2,786,638.61
3,906.00
67,603.05
8,674.12

1,438,135
1,940
16,148
1,696

1,309,373
1,766
14,702
1,544

1,644,464
2,374
56,957
7,650

2,866,821.78

1,457,919

1,327,386

1,711,445

15.24
15.28
15.47
15.47

107,904
155
3,682
495
112,236

 Attachment to Response to AG-2 Question No. 33(c)
Page 81 of 149
Spanos

BROWN CT 6
INTERIM SURVIVOR CURVE.. IOWA 55-S2.5
PROBABLE RETIREMENT YEAR.. 6-2029
NET SALVAGE PERCENT.. -6
1999
2012

3,712,619.52
8,674.11

2,177,050
1,894

1,992,671
1,734

1,942,705
7,461

3,721,293.63

2,178,944

1,994,405

1,950,166

13.27
13.49

146,398
553
146,951

BROWN CT 7
INTERIM SURVIVOR CURVE.. IOWA 55-S2.5
PROBABLE RETIREMENT YEAR.. 6-2029
NET SALVAGE PERCENT.. -6
1999
2001
2012

3,693,120.46
29,668.00
8,674.11

2,165,616
16,369
1,894

1,955,274
14,779
1,710

1,959,434
16,669
7,485

3,731,462.57

2,183,879

1,971,763

1,983,587

13.27
13.33
13.49

147,659
1,250
555
149,464

BROWN CT 8
INTERIM SURVIVOR CURVE.. IOWA 55-S2.5
PROBABLE RETIREMENT YEAR.. 6-2025
NET SALVAGE PERCENT.. -6
1995
2012

4,953,960.72
8,674.11

3,599,802
2,475

3,435,112
2,362

1,816,086
6,833

4,962,634.83

3,602,277

3,437,474

1,822,919

9.34
9.50

194,442
719
195,161

BROWN CT 9
INTERIM SURVIVOR CURVE.. IOWA 55-S2.5
PROBABLE RETIREMENT YEAR.. 6-2031
NET SALVAGE PERCENT.. -6
1994
1995
2012

5,333,167.97
118,873.00
8,674.11

3,329,880
72,662
1,696

3,521,232
76,838
1,793

2,131,926
49,168
7,401

5,460,715.08

3,404,238

3,599,863

2,188,495

14.84
14.91
15.47

143,661
3,298
478
147,437

 Attachment to Response to AG-2 Question No. 33(c)
Page 82 of 149
Spanos

BROWN CT 10
INTERIM SURVIVOR CURVE.. IOWA 55-S2.5
PROBABLE RETIREMENT YEAR.. 6-2031
NET SALVAGE PERCENT.. -6
1995
2012

4,944,422.71
8,674.11

3,022,326
1,696

3,127,299
1,755

2,113,789
7,440

4,953,096.82

3,024,022

3,129,054

2,121,229

14.91
15.47

141,770
481
142,251

BROWN CT 11
INTERIM SURVIVOR CURVE.. IOWA 55-S2.5
PROBABLE RETIREMENT YEAR.. 6-2026
NET SALVAGE PERCENT.. -6
1996
1997
2012
2013

4,573,326.33
119,111.00
8,674.11
1,061,783.54

3,163,287
80,849
2,299
216,443

2,601,158
66,482
1,890
177,980

2,246,568
59,776
7,304
947,510

5,762,894.98

3,462,878

2,847,510

3,261,159

10.32
10.34
10.50
10.50

217,691
5,781
696
90,239
314,407

HAEFLING UNITS 1, 2 AND 3
INTERIM SURVIVOR CURVE.. IOWA 55-S2.5
PROBABLE RETIREMENT YEAR.. 6-2020
NET SALVAGE PERCENT.. -10
1970
1971
1975
2001

2,280,419.06
146,547.00
18,497.00
236,672.62

2,279,915
146,237
18,306
198,720

2,019,725
129,548
16,217
176,042

488,736
31,654
4,130
84,298

2,682,135.68

2,643,178

2,341,531

608,818

4.19
4.21
4.27
4.49

116,643
7,519
967
18,775
143,904

 Attachment to Response to AG-2 Question No. 33(c)
Page 83 of 149
Spanos

PADDY'S RUN GENERATOR 13
INTERIM SURVIVOR CURVE.. IOWA 55-S2.5
PROBABLE RETIREMENT YEAR.. 6-2031
NET SALVAGE PERCENT.. -6
2001
2002
2012
2014

4,940,529.59
11,002.00
26,588.67
472,429.16

2,549,719
5,464
5,200
44,213

2,221,371
4,760
4,530
38,519

3,015,590
6,902
23,654
462,256

15.24
15.28
15.47
15.49

5,450,549.42

2,604,596

2,269,181

3,508,401

229,696

172,508,939.62

34,738,993

32,807,403

154,890,238

5,540,469

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 28.0

197,873
452
1,529
29,842

3.21

 Attachment to Response to AG-2 Question No. 33(c)
Page 84 of 149
Spanos

CANE RUN CC 7
INTERIM SURVIVOR CURVE.. IOWA 50-R3
PROBABLE RETIREMENT YEAR.. 6-2055
NET SALVAGE PERCENT.. -10
2015

26,286,452.56

375,318

421,424

28,493,674

26,286,452.56

375,318

421,424

28,493,674

37.25

764,931
764,931

TRIMBLE COUNTY CT 5
INTERIM SURVIVOR CURVE.. IOWA 50-R3
PROBABLE RETIREMENT YEAR.. 6-2032
NET SALVAGE PERCENT.. -7
2002
2004
2011
2012
2014

1,645,529.86
12,857.15
24,962.92
68,399.27
138,194.66

797,534
5,684
5,736
12,826
12,337

721,538
5,142
5,189
11,604
11,161

1,039,179
8,615
21,521
61,583
136,707

1,889,943.86

834,117

754,635

1,267,605

15.99
16.08
16.31
16.33
16.37

64,989
536
1,319
3,771
8,351
78,966

TRIMBLE COUNTY CT 6
INTERIM SURVIVOR CURVE.. IOWA 50-R3
PROBABLE RETIREMENT YEAR.. 6-2032
NET SALVAGE PERCENT.. -7
2002
2004
2012

4,313,237.34
11,354.12
5,249.63

2,090,485
5,019
984

1,683,398
4,042
792

2,931,766
8,107
4,825

4,329,841.09

2,096,488

1,688,232

2,944,698

15.99
16.08
16.33

183,350
504
295
184,149

TRIMBLE COUNTY CT 7
INTERIM SURVIVOR CURVE.. IOWA 50-R3
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
2004
2009
2012
2013
2014

3,136,584.26
2,204.23
22,579.92
50,147.90
621,521.71

1,297,452
617
3,858
6,407
50,043

1,194,784
568
3,553
5,900
46,083

2,161,361
1,790
20,608
47,758
618,945

3,833,038.02

1,358,377

1,250,888

2,850,463

17.93
18.16
18.26
18.29
18.31

120,544
99
1,129
2,611
33,804
158,187

 Attachment to Response to AG-2 Question No. 33(c)
Page 85 of 149
Spanos

TRIMBLE COUNTY CT 8
INTERIM SURVIVOR CURVE.. IOWA 50-R3
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
2004
2009
2012

3,137,127.45
2,204.23
5,249.63

1,297,677
617
897

1,228,387
584
849

2,128,340
1,774
4,768

3,144,581.31

1,299,191

1,229,820

2,134,882

17.93
18.16
18.26

118,703
98
261
119,062

TRIMBLE COUNTY CT 9
INTERIM SURVIVOR CURVE.. IOWA 50-R3
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
2004
2009
2012
2014

3,222,176.42
2,204.19
22,579.92
176,314.04

1,332,857
617
3,858
14,196

1,239,857
574
3,589
13,205

2,207,872
1,785
20,572
175,451

3,423,274.57

1,351,528

1,257,225

2,405,679

17.93
18.16
18.26
18.31

123,138
98
1,127
9,582
133,945

TRIMBLE COUNTY CT 10
INTERIM SURVIVOR CURVE.. IOWA 50-R3
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
2004
2009
2011
2012
2013

7,144,489.03
2,204.23
49,925.08
5,249.63
59,208.10

2,955,327
617
10,500
897
7,564

2,496,860
521
8,871
758
6,391

5,147,743
1,837
44,549
4,859
56,962

7,261,076.07

2,974,905

2,513,401

5,255,950

17.93
18.16
18.23
18.26
18.29

287,102
101
2,444
266
3,114
293,027

 Attachment to Response to AG-2 Question No. 33(c)
Page 86 of 149
Spanos

BROWN CT 5
INTERIM SURVIVOR CURVE.. IOWA 50-R3
PROBABLE RETIREMENT YEAR.. 6-2031
NET SALVAGE PERCENT.. -6
2001
2002
2010
2012

2,262,097.84
3,069.00
11,853.65
33,212.26

1,164,863
1,522
3,297
6,488

993,869
1,299
2,813
5,536

1,403,955
1,955
9,752
29,669

2,310,232.75

1,176,170

1,003,516

1,445,331

15.03
15.07
15.32
15.36

93,410
130
637
1,932
96,109

BROWN CT 6
INTERIM SURVIVOR CURVE.. IOWA 50-R3
PROBABLE RETIREMENT YEAR.. 6-2029
NET SALVAGE PERCENT.. -6
1999
2010
2012
2013

1,930,284.42
44,931.99
41,923.74
9,502.80

1,129,100
13,810
9,162
1,577

966,413
11,820
7,842
1,350

1,079,688
35,808
36,597
8,723

2,026,642.95

1,153,649

987,425

1,160,817

13.10
13.37
13.40
13.41

82,419
2,678
2,731
650
88,478

BROWN CT 7
INTERIM SURVIVOR CURVE.. IOWA 50-R3
PROBABLE RETIREMENT YEAR.. 6-2029
NET SALVAGE PERCENT.. -6
1999
2010
2012
2013

1,920,146.21
15,635.77
41,923.74
9,502.80

1,123,170
4,806
9,162
1,577

952,813
4,077
7,772
1,338

1,082,542
12,497
36,667
8,735

1,987,208.52

1,138,715

966,000

1,140,441

775,317
648,903
176,712

547,652
490,707
144,238

13.10
13.37
13.40
13.41

82,637
935
2,736
651
86,959

BROWN CT 8
INTERIM SURVIVOR CURVE.. IOWA 50-R3
PROBABLE RETIREMENT YEAR.. 6-2025
NET SALVAGE PERCENT.. -6
1993
1995
1997

1,248,083.99
1,075,103.50
302,783.00

930,722
778,969
212,132

9.20
9.25
9.29

59,527
53,049
15,526

 Attachment to Response to AG-2 Question No. 33(c)
Page 87 of 149
Spanos

BROWN CT 8
INTERIM SURVIVOR CURVE.. IOWA 50-R3
PROBABLE RETIREMENT YEAR.. 6-2025
NET SALVAGE PERCENT.. -6
2007
2012
2014

10,526.68
530,214.36
159,624.16

5,267
151,466
23,137

4,388
126,175
19,274

6,771
435,852
149,928

3,326,335.69

2,101,693

1,750,769

1,775,147

9.43
9.46
9.47

718
46,073
15,832
190,725

BROWN CT 9
INTERIM SURVIVOR CURVE.. IOWA 50-R3
PROBABLE RETIREMENT YEAR.. 6-2031
NET SALVAGE PERCENT.. -6
1994
1995
1996
1997
2011
2012
2014

1,895,387.28
1,463,066.43
293,484.00
336,423.00
217,486.58
353,258.42
148,050.77

1,177,720
890,312
174,598
195,386
51,928
69,004
13,853

1,141,993
863,304
169,301
189,459
50,353
66,911
13,433

867,117
687,546
141,792
167,149
180,183
307,543
143,501

4,707,156.48

2,572,801

2,494,754

2,494,832

14.62
14.69
14.76
14.82
15.34
15.36
15.39

59,310
46,804
9,607
11,279
11,746
20,022
9,324
168,092

BROWN CT 10
INTERIM SURVIVOR CURVE.. IOWA 50-R3
PROBABLE RETIREMENT YEAR.. 6-2031
NET SALVAGE PERCENT.. -6
1993
1995
1997
2012
2014

940,073.23
1,483,977.47
320,442.00
353,258.41
148,140.76

595,684
903,037
186,104
69,004
13,861

559,270
847,835
174,728
64,786
13,014

437,207
725,181
164,941
309,668
144,016

3,245,891.87

1,767,690

1,659,633

1,781,012

14.54
14.69
14.82
15.36
15.39

30,069
49,366
11,130
20,161
9,358
120,084

 Attachment to Response to AG-2 Question No. 33(c)
Page 88 of 149
Spanos

BROWN CT 11
INTERIM SURVIVOR CURVE.. IOWA 50-R3
PROBABLE RETIREMENT YEAR.. 6-2026
NET SALVAGE PERCENT.. -6
1996
1997
2012
2014

1,767,686.75
35,427.00
477,155.79
173,988.88

1,219,248
23,987
126,355
23,131

1,209,195
23,789
125,313
22,940

664,553
13,763
380,472
161,488

2,454,258.42

1,392,721

1,381,238

1,220,276

10.21
10.23
10.45
10.46

65,088
1,345
36,409
15,439
118,281

HAEFLING UNITS 1, 2 AND 3
INTERIM SURVIVOR CURVE.. IOWA 50-R3
PROBABLE RETIREMENT YEAR.. 6-2020
NET SALVAGE PERCENT.. -10
1970
1971
1973
2007
2012

199,408.97
41,999.00
2,825.81
19,643.19
552,386.44

199,082
41,844
2,803
14,116
265,739

40,159
8,441
565
2,848
53,606

179,190
37,758
2,543
18,760
554,019

816,263.41

523,584

105,619

792,271

4.11
4.14
4.19
4.49
4.49

43,599
9,120
607
4,178
123,390
180,894

PADDY'S RUN GENERATOR 13
INTERIM SURVIVOR CURVE.. IOWA 50-R3
PROBABLE RETIREMENT YEAR.. 6-2031
NET SALVAGE PERCENT.. -6
2001
2002
2012
2014
2015

2,416,310.20
5,178.00
25,073.74
10,513.67
42,575.01

1,244,274
2,568
4,898
984
1,419

1,132,321
2,337
4,457
895
1,291

1,428,968
3,152
22,121
10,249
43,838

15.03
15.07
15.36
15.39
15.40

2,499,650.62

1,254,143

1,141,302

1,508,328

100,236

73,541,848.19

23,371,090

20,605,881

58,671,406

2,882,125

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 20.4

95,074
209
1,440
666
2,847

3.92

 Attachment to Response to AG-2 Question No. 33(c)
Page 89 of 149
Spanos

CANE RUN CC 7
INTERIM SURVIVOR CURVE.. IOWA 40-R2
PROBABLE RETIREMENT YEAR.. 6-2055
NET SALVAGE PERCENT.. -10
2015

21,065.55

313

88

23,084

21,065.55

313

88

23,084

33.56

688
688

TRIMBLE COUNTY CT 5
INTERIM SURVIVOR CURVE.. IOWA 40-R2
PROBABLE RETIREMENT YEAR.. 6-2032
NET SALVAGE PERCENT.. -7
2006
2007

15,274.16
13,689.47

5,950
4,960

7,024
5,856

9,319
8,792

28,963.63

10,910

12,880

18,111

15.46
15.53

603
566
1,169

TRIMBLE COUNTY CT 7
INTERIM SURVIVOR CURVE.. IOWA 40-R2
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
2004

8,888.93

3,653

3,661

5,850

8,888.93

3,653

3,661

5,850

16.92

346
346

TRIMBLE COUNTY CT 8
INTERIM SURVIVOR CURVE.. IOWA 40-R2
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
2004

8,861.01

3,641

3,649

5,832

8,861.01

3,641

3,649

5,832

16.92

345
345

 Attachment to Response to AG-2 Question No. 33(c)
Page 90 of 149
Spanos

TRIMBLE COUNTY CT 9
INTERIM SURVIVOR CURVE.. IOWA 40-R2
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
2004

9,113.52

3,745

3,730

6,021

9,113.52

3,745

3,730

6,021

16.92

356
356

TRIMBLE COUNTY CT 10
INTERIM SURVIVOR CURVE.. IOWA 40-R2
PROBABLE RETIREMENT YEAR.. 6-2034
NET SALVAGE PERCENT.. -7
2004
2010
2011

9,105.52
26,747.06
6,015.93

3,742
6,536
1,255

3,657
6,388
1,226

6,086
22,232
5,211

41,868.51

11,533

11,271

33,528

16.92
17.47
17.54

360
1,273
297
1,930

BROWN CT 5
INTERIM SURVIVOR CURVE.. IOWA 40-R2
PROBABLE RETIREMENT YEAR.. 6-2031
NET SALVAGE PERCENT.. -6
2001
2002
2003
2004
2007

2,082,373.17
2,790.00
998.32
22,748.93
30,442.19

1,063,882
1,371
470
10,223
11,360

1,044,238
1,346
461
10,034
11,150

1,163,078
1,612
597
14,080
21,118

2,139,352.61

1,087,306

1,067,229

1,200,485

8,674
1,104
7,738

8,137
1,169
9,432

14.23
14.32
14.40
14.47
14.67

81,734
113
41
973
1,440
84,301

BROWN CT 6
INTERIM SURVIVOR CURVE.. IOWA 40-R2
PROBABLE RETIREMENT YEAR.. 6-2029
NET SALVAGE PERCENT.. -6
1999
2001
2003

15,859.82
2,144.00
16,198.37

9,192
1,170
8,200

12.45
12.58
12.70

654
93
743

 Attachment to Response to AG-2 Question No. 33(c)
Page 91 of 149
Spanos

BROWN CT 6
INTERIM SURVIVOR CURVE.. IOWA 40-R2
PROBABLE RETIREMENT YEAR.. 6-2029
NET SALVAGE PERCENT.. -6
2005
2011
2015

14,757.51
4,789.15
48,476.11

6,792
1,260
1,843

6,409
1,189
1,739

9,234
3,887
49,645

102,224.96

28,457

26,854

81,504

12.81
13.05
13.17

721
298
3,770
6,279

BROWN CT 7
INTERIM SURVIVOR CURVE.. IOWA 40-R2
PROBABLE RETIREMENT YEAR.. 6-2029
NET SALVAGE PERCENT.. -6
1999
2003
2015

15,776.54
19,870.85
48,476.09

9,144
10,059
1,843

9,436
10,380
1,902

7,288
10,683
49,483

84,123.48

21,046

21,717

67,454

12.45
12.70
13.17

585
841
3,757
5,183

BROWN CT 8
INTERIM SURVIVOR CURVE.. IOWA 40-R2
PROBABLE RETIREMENT YEAR.. 6-2025
NET SALVAGE PERCENT.. -6
1994
1995
2001
2011
2012

34,743.72
185,434.00
9,891.00
55,863.61
5,293.68

25,314
133,091
6,280
18,900
1,497

24,732
130,030
6,136
18,465
1,463

12,097
66,530
4,349
40,750
4,149

291,226.01

185,082

180,825

127,875

135,915
371,585
3,460

72,298
210,047
2,080

8.82
8.87
9.08
9.30
9.32

1,372
7,501
479
4,382
445
14,179

BROWN CT 9
INTERIM SURVIVOR CURVE.. IOWA 40-R2
PROBABLE RETIREMENT YEAR.. 6-2031
NET SALVAGE PERCENT.. -6
1994
1995
1996

196,427.37
548,710.00
5,227.00

121,290
331,600
3,088

13.48
13.61
13.73

5,363
15,433
151

 Attachment to Response to AG-2 Question No. 33(c)
Page 92 of 149
Spanos

BROWN CT 9
INTERIM SURVIVOR CURVE.. IOWA 40-R2
PROBABLE RETIREMENT YEAR.. 6-2031
NET SALVAGE PERCENT.. -6
2001
2014
2015

9,891.00
66,684.25
33,485.67

5,053
6,231
1,098

5,662
6,982
1,230

4,822
63,703
34,264

860,425.29

468,360

524,836

387,215

14.23
15.00
15.04

339
4,247
2,278
27,811

BROWN CT 10
INTERIM SURVIVOR CURVE.. IOWA 40-R2
PROBABLE RETIREMENT YEAR.. 6-2031
NET SALVAGE PERCENT.. -6
1995
1996
2001
2003

228,488.31
3,144.00
9,891.00
32,867.56

138,082
1,858
5,053
15,484

146,888
1,976
5,375
16,471

95,310
1,356
5,109
18,368

274,390.87

160,477

170,711

120,143

13.61
13.73
14.23
14.40

7,003
99
359
1,276
8,737

BROWN CT 11
INTERIM SURVIVOR CURVE.. IOWA 40-R2
PROBABLE RETIREMENT YEAR.. 6-2026
NET SALVAGE PERCENT.. -6
1996
1997
1999
2001
2003
2004
2005
2011

149,568.53
21,262.00
9,687.00
24,337.00
277,131.30
46,587.64
20,014.16
41,975.19

102,155
14,257
6,221
14,832
158,272
25,588
10,518
13,235

95,861
13,379
5,838
13,918
148,520
24,011
9,870
12,420

62,682
9,159
4,431
11,879
145,239
25,372
11,345
32,074

590,562.82

345,078

323,816

302,181

9.77
9.81
9.90
9.98
10.05
10.08
10.11
10.25

6,416
934
448
1,190
14,452
2,517
1,122
3,129
30,208

 Attachment to Response to AG-2 Question No. 33(c)
Page 93 of 149
Spanos

HAEFLING UNITS 1, 2 AND 3
INTERIM SURVIVOR CURVE.. IOWA 40-R2
PROBABLE RETIREMENT YEAR.. 6-2020
NET SALVAGE PERCENT.. -10
1970
1971
1973
2013

30,264.20
5,384.33
113.00
69,229.69

29,970
5,321
111
27,033

17,059
3,029
63
15,387

16,232
2,894
61
60,765

104,991.22

62,435

35,538

79,952

3.80
3.84
3.92
4.47

4,272
754
16
13,594
18,636

PADDY'S RUN GENERATOR 13
INTERIM SURVIVOR CURVE.. IOWA 40-R2
PROBABLE RETIREMENT YEAR.. 6-2031
NET SALVAGE PERCENT.. -6
2001
2002

1,086,962.03
2,588.00

555,328
1,272

545,052
1,248

607,128
1,495

14.23
14.32

1,089,550.03

556,600

546,300

608,623

42,769

5,655,608.44

2,948,636

2,933,105

3,067,858

242,937

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 12.6

42,665
104

4.30

 Attachment to Response to AG-2 Question No. 33(c)
Page 94 of 149
Spanos

SURVIVOR CURVE.. IOWA 70-R3
NET SALVAGE PERCENT.. 0
1941
1942
1943
1944
1945
1946
1947
1948
1949
1950
1951
1952
1953
1954
1955
1956
1957
1958
1959
1960
1961
1962
1963
1964
1965
1966
1967
1968
1969
1970
1971
1972
1973
1974
1975
1976
1977
1978
1979
1980
1981
1982
1983

686,361.06
27,091.62
1,077.00
860.00
5,395.00
38,829.00
65,530.00
33,277.00
228,344.00
22,549.00
104,789.00
186,048.00
409,306.00
108,821.00
85,914.00
259,450.00
32,179.00
373,514.00
226,833.00
263,434.00
327,284.00
280,359.36
465,120.00
93,142.00
287,634.00
415,879.00
611,565.00
128,655.00
402,094.00
1,682,695.00
970,069.00
593,107.00
978,038.00
542,946.00
172,802.00
454,641.00
141,182.00
902,286.00
881,852.00
758,709.00
572,541.00
859,510.00
315,498.00

567,229
22,231
877
695
4,324
30,864
51,638
25,985
176,640
17,276
79,475
139,642
303,881
79,906
62,362
186,101
22,797
261,299
156,612
179,435
219,840
185,637
303,458
59,850
181,949
258,856
374,455
77,432
237,754
977,158
552,804
331,547
535,965
291,486
90,844
233,881
71,015
443,410
423,033
355,076
261,159
381,743
136,339

686,361
27,092
1,077
860
5,395
38,829
65,530
33,277
228,344
22,549
104,789
186,048
409,306
108,821
85,914
259,450
32,179
371,912
222,909
255,394
312,903
264,221
431,918
85,186
258,972
368,435
532,970
110,211
338,400
1,390,809
786,817
471,898
762,850
414,878
129,300
332,888
101,077
631,115
602,112
505,387
371,713
543,343
194,054

1,602
3,924
8,040
14,381
16,138
33,202
7,956
28,662
47,444
78,595
18,444
63,694
291,886
183,252
121,209
215,188
128,068
43,502
121,753
40,105
271,171
279,740
253,322
200,828
316,167
121,444

21.03
21.67
22.32
22.98
23.65
24.33
25.02
25.72
26.43
27.14
27.87
28.61
29.35
30.11
30.87
31.64
32.42
33.20
33.99
34.79
35.60
36.42
37.24
38.07
38.91
39.75

76
181
360
626
682
1,365
318
1,114
1,795
2,896
662
2,226
9,945
6,086
3,926
6,801
3,950
1,310
3,582
1,153
7,617
7,681
6,802
5,275
8,126
3,055

 Attachment to Response to AG-2 Question No. 33(c)
Page 95 of 149
Spanos

SURVIVOR CURVE.. IOWA 70-R3
NET SALVAGE PERCENT.. 0
1984
1985
1986
1987
1988
1989
1990
1991
1992
1993
1994
1995
1996
1997
1998
1999
2000
2003
2005
2009
2010
2011
2012
2013
2014

2,222,027.00
1,379,271.00
169,584.00
604,324.00
124,766.00
125,746.00
125,552.00
308,966.00
56,034.00
47,759.00
84,416.00
414,604.00
75,397.00
64,154.96
315,419.00
347,323.37
70,004.00
349,837.18
545.00
353,837.52
152,130.15
24,821.33
3,922,392.56
1,801,301.84
291,572.35

933,251
562,343
67,059
231,456
46,217
44,999
43,333
102,710
17,907
14,641
24,782
116,325
20,153
16,304
75,972
78,992
14,981
60,672
80
32,150
11,714
1,564
192,746
63,298
6,164

1,328,315
800,394
95,446
329,436
65,782
64,048
61,677
146,189
25,487
20,839
35,273
165,568
28,684
23,206
108,133
112,431
21,323
86,356
114
45,760
16,673
2,226
274,339
90,093
8,773

893,712
578,877
74,138
274,888
58,984
61,698
63,875
162,777
30,547
26,920
49,143
249,036
46,713
40,949
207,286
234,892
48,681
263,481
431
308,078
135,457
22,595
3,648,054
1,711,209
282,799

29,428,995.30

12,133,773

17,044,058

12,384,937

40.60
41.46
42.32
43.19
44.07
44.95
45.84
46.73
47.63
48.54
49.45
50.36
51.29
52.21
53.14
54.08
55.02
57.86
59.77
63.64
64.61
65.59
66.56
67.54
68.52

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 48.9

22,013
13,962
1,752
6,365
1,338
1,373
1,393
3,483
641
555
994
4,945
911
784
3,901
4,343
885
4,554
7
4,841
2,097
344
54,809
25,336
4,127
253,363
0.86

 Attachment to Response to AG-2 Question No. 33(c)
Page 96 of 149
Spanos

SURVIVOR CURVE.. IOWA 70-R3
NET SALVAGE PERCENT.. -25
1940
1941
1947
1948
1949
1950
1951
1952
1953
1954
1955
1956
1957
1958
1959
1960
1961
1962
1963
1964
1965
1966
1967
1968
1969
1970
1971
1972
1973
1974
1975
1976
1977
1978
1979
1980
1981
1982
1983
1984
1985
1986
1987

1,901.21
42,347.02
3,222.45
1,400.50
24,234.72
22,123.18
26,145.14
2,055.05
28,141.84
46,002.37
13,433.92
161,112.14
13,238.93
49,232.11
37,746.86
37,268.81
17,168.99
12,553.11
11,844.93
42,399.73
32,209.35
45,936.12
12,722.00
13,800.95
39,890.18
70,548.61
125,888.81
199,094.35
26,126.25
32,497.65
83,479.24
43,600.10
226,179.21
201,284.69
212,287.33
195,674.53
966,223.83
700,284.66
431,367.27
212,916.21
112,188.04
53,056.45
133,190.84

1,978
43,746
3,174
1,367
23,434
21,187
24,787
1,928
26,117
42,224
12,189
144,455
11,724
43,052
32,577
31,732
14,416
10,390
9,660
34,056
25,468
35,740
9,737
10,383
29,483
51,210
89,674
139,117
17,896
21,808
54,857
28,036
142,210
123,647
127,295
114,470
550,917
388,781
233,014
111,781
57,175
26,225
63,765

2,377
52,934
3,909
1,683
28,859
26,092
30,525
2,374
32,163
51,998
15,011
177,895
14,438
53,018
40,118
39,078
17,753
12,795
11,896
41,940
31,364
44,013
11,991
12,787
36,308
63,065
110,432
171,321
22,039
26,856
67,556
34,526
175,130
152,270
156,762
140,968
678,448
478,779
286,954
137,657
70,410
32,296
78,526

119
68
1,434
1,562
2,156
195
3,014
5,505
1,781
23,495
2,111
8,522
7,066
7,508
3,708
2,896
2,910
11,060
8,898
13,407
3,912
4,464
13,555
25,121
46,929
77,547
10,619
13,766
36,793
19,974
107,594
99,336
108,597
103,625
529,332
396,577
252,255
128,488
69,825
34,025
87,963

14.84
15.34
15.85
16.37
16.91
17.46
18.03
18.60
19.19
19.79
20.41
21.03
21.67
22.32
22.98
23.65
24.33
25.02
25.72
26.43
27.14
27.87
28.61
29.35
30.11
30.87
31.64
32.42
33.20
33.99
34.79
35.60
36.42
37.24
38.07
38.91
39.75
40.60
41.46
42.32
43.19

8
4
90
95
127
11
167
296
93
1,187
103
405
326
336
161
122
120
442
346
507
144
160
474
856
1,559
2,512
336
425
1,108
588
3,093
2,790
2,982
2,783
13,904
10,192
6,346
3,165
1,684
804
2,037

 Attachment to Response to AG-2 Question No. 33(c)
Page 97 of 149
Spanos

SURVIVOR CURVE.. IOWA 70-R3
NET SALVAGE PERCENT.. -25
1988
1989
1990
1991
1992
1993
1994
1995
1996
1997
1998
1999
2000
2001
2002
2003
2004
2005
2007
2008
2009
2010
2011
2012
2013
2014
2015

114,353.09
17,100.34
171,913.94
7,702.35
141,734.20
102,402.67
299,706.89
479,982.26
105,458.55
95,464.07
633,320.49
27,077.02
204,160.00
150,801.95
81,986.71
38,594.54
293,527.04
191,745.22
199,665.65
5,336,706.92
2,352,857.19
130,562.84
1,453,389.24
891,090.53
3,666,932.75
2,085,586.37
1,276,621.32

52,950
7,649
74,168
3,201
56,617
39,242
109,981
168,336
35,235
30,327
190,677
7,698
54,613
37,808
19,164
8,367
58,654
35,027
29,593
698,508
267,226
12,567
114,454
54,735
161,070
55,112
11,170

65,207
9,420
91,337
3,942
69,723
48,326
135,440
207,304
43,392
37,347
234,817
9,480
67,255
46,560
23,600
10,304
72,232
43,135
36,443
860,206
329,086
15,476
140,949
67,406
198,356
67,869
13,756

77,734
11,955
123,555
5,686
107,445
79,677
239,194
392,674
88,431
81,983
556,834
24,366
187,945
141,942
78,883
37,939
294,677
196,547
213,139
5,810,678
2,611,985
147,728
1,675,788
1,046,457
4,385,310
2,539,114
1,582,021

25,314,463.82

5,381,031

6,625,682

25,017,398

44.07
44.95
45.84
46.73
47.63
48.54
49.45
50.36
51.29
52.21
53.14
54.08
55.02
55.96
56.91
57.86
58.81
59.77
61.70
62.67
63.64
64.61
65.59
66.56
67.54
68.52
69.51

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 59.5

1,764
266
2,695
122
2,256
1,641
4,837
7,797
1,724
1,570
10,479
451
3,416
2,536
1,386
656
5,011
3,288
3,454
92,719
41,043
2,286
25,549
15,722
64,929
37,057
22,760
420,302
1.66

 Attachment to Response to AG-2 Question No. 33(c)
Page 98 of 149
Spanos

SURVIVOR CURVE.. IOWA 65-R4
NET SALVAGE PERCENT.. -25
1956
1958
1960
1962
1968
1974
1988
1997
2011

17,016.61
9,243.36
35.08
26.03
50.32
6,614.02
4,541.07
77,868.93
77,830.59

17,197
9,121
34
24
43
5,032
2,364
27,524
6,721

18,185
9,645
36
25
45
5,321
2,500
29,106
7,107

3,086
1,909
8
8
18
2,947
3,176
68,230
90,181

193,226.01

68,060

71,970

169,563

12.45
13.69
15.00
16.36
20.69
25.44
37.93
46.62
60.51

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 47.9

248
139
1
1
116
84
1,464
1,490
3,543
1.83

 Attachment to Response to AG-2 Question No. 33(c)
Page 99 of 149
Spanos

SURVIVOR CURVE.. IOWA 60-R2
NET SALVAGE PERCENT.. -15
1929
1940
1941
1942
1943
1944
1945
1946
1947
1948
1949
1950
1951
1952
1953
1954
1955
1956
1957
1958
1959
1960
1961
1962
1963
1964
1965
1966
1967
1968
1969
1970
1971
1972
1973
1974
1975
1976
1977
1978
1979
1980
1981

1,329.06
614.96
1,577.30
3,185.97
6,406.69
2,571.36
16,249.99
23,097.96
10,076.59
18,358.68
460,870.87
679,885.12
389,755.98
102,589.77
2,060,125.68
192,644.52
1,293,855.69
1,178,902.86
1,586,495.86
15,987.39
595,989.03
350,377.01
519,477.18
358,532.14
992,783.17
1,103,159.69
992,755.06
768,602.09
284,326.58
456,958.19
2,819,648.41
1,956,880.52
3,018,845.94
1,533,551.57
838,327.57
1,647,063.80
1,309,959.20
468,961.96
7,943,911.51
2,083,272.53
3,795,491.58
6,499,049.23
3,247,892.39

1,352
585
1,491
2,990
5,968
2,377
14,906
21,020
9,095
16,429
408,896
597,738
339,450
88,504
1,759,493
162,833
1,082,219
975,223
1,297,800
12,925
476,118
276,412
404,636
275,560
752,757
824,612
731,433
557,736
203,160
321,344
1,949,870
1,330,376
2,016,452
1,005,825
539,719
1,039,874
810,728
284,214
4,712,364
1,208,663
2,151,854
3,598,686
1,754,851

1,370
593
1,511
3,030
6,048
2,409
15,106
21,302
9,217
16,650
414,388
605,766
344,009
89,693
1,783,126
165,020
1,096,755
988,322
1,315,231
13,099
482,513
280,125
410,071
279,261
762,868
835,688
741,257
565,227
205,889
325,660
1,976,060
1,348,245
2,043,536
1,019,335
546,968
1,053,841
821,617
288,031
4,775,658
1,224,897
2,180,756
3,647,021
1,778,421

158
114
303
634
1,320
548
3,581
5,261
2,371
4,462
115,614
176,102
104,210
28,285
586,019
56,521
391,179
367,416
509,239
5,286
202,874
122,809
187,328
133,051
378,833
432,946
400,411
318,665
121,087
199,842
1,266,536
902,168
1,428,137
744,249
417,109
840,282
684,836
251,275
4,359,840
1,170,866
2,184,059
3,826,886
1,956,655

6.93
10.35
10.69
11.04
11.40
11.76
12.14
12.52
12.91
13.31
13.71
14.13
14.56
14.99
15.44
15.90
16.36
16.84
17.32
17.82
18.32
18.84
19.36
19.90
20.44
21.00
21.56
22.14
22.72
23.31
23.92
24.53
25.15
25.78
26.41
27.06
27.71
28.38
29.05
29.73
30.42
31.11
31.81

23
11
28
57
116
47
295
420
184
335
8,433
12,463
7,157
1,887
37,955
3,555
23,911
21,818
29,402
297
11,074
6,519
9,676
6,686
18,534
20,616
18,572
14,393
5,330
8,573
52,949
36,778
56,785
28,869
15,794
31,053
24,714
8,854
150,081
39,383
71,797
123,011
61,511

 Attachment to Response to AG-2 Question No. 33(c)
Page 100 of 149
Spanos

SURVIVOR CURVE.. IOWA 60-R2
NET SALVAGE PERCENT.. -15
1982
1983
1984
1985
1986
1987
1988
1989
1990
1991
1992
1993
1994
1995
1996
1997
1998
1999
2000
2001
2002
2003
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015

9,635,152.70
1,605,263.83
3,100,245.72
6,924,282.01
408,753.93
322,854.77
2,290,454.44
1,656,388.49
1,380,098.71
1,158,687.52
7,182,903.62
2,367,410.60
1,521,675.18
3,696,636.77
2,312,766.67
3,894,099.17
3,843,836.90
1,059,125.44
3,361,549.26
156,600.10
698,980.26
13,062,138.98
2,377,597.37
3,340,402.36
2,976,240.72
2,708,418.47
6,520,763.07
10,938,738.65
10,711,770.63
7,037,833.48
35,675,668.49
13,590,385.40
23,688,207.28
14,899,307.63

5,074,835
823,340
1,546,727
3,357,726
192,413
147,336
1,012,334
707,974
569,504
460,815
2,749,289
870,744
536,352
1,246,304
744,259
1,192,683
1,116,906
290,894
870,458
38,030
158,491
2,751,481
461,621
594,159
480,304
391,920
834,850
1,216,065
1,010,120
544,936
2,153,918
586,085
617,563
128,507

5,142,997
834,399
1,567,502
3,402,825
194,997
149,315
1,025,931
717,483
577,153
467,004
2,786,216
882,439
543,556
1,263,044
754,255
1,208,703
1,131,908
294,801
882,150
38,541
160,620
2,788,437
467,821
602,139
486,755
397,184
846,063
1,232,399
1,023,687
552,255
2,182,849
593,957
625,858
130,233

5,937,429
1,011,654
1,997,781
4,560,099
275,070
221,968
1,608,092
1,187,364
1,009,961
865,487
5,474,123
1,840,083
1,206,370
2,988,088
1,905,427
3,269,511
3,288,504
923,193
2,983,632
141,549
643,207
12,233,023
2,266,416
3,239,324
2,935,922
2,717,497
6,652,815
11,347,150
11,294,849
7,541,254
38,844,170
15,034,986
26,615,580
17,003,971

257,735,637.27

69,507,481

70,441,066

225,954,917

32.52
33.24
33.97
34.70
35.44
36.19
36.94
37.70
38.47
39.25
40.03
40.81
41.61
42.41
43.21
44.02
44.84
45.67
46.49
47.33
48.17
49.01
49.87
50.72
51.58
52.45
53.32
54.20
55.08
55.96
56.85
57.75
58.64
59.55

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 46.0

182,578
30,435
58,810
131,415
7,762
6,133
43,533
31,495
26,253
22,051
136,751
45,089
28,992
70,457
44,097
74,273
73,339
20,214
64,178
2,991
13,353
249,603
45,446
63,867
56,920
51,811
124,771
209,357
205,063
134,762
683,275
260,346
453,881
285,541
4,908,788
1.90

 Attachment to Response to AG-2 Question No. 33(c)
Page 101 of 149
Spanos

SURVIVOR CURVE.. IOWA 45-R2
NET SALVAGE PERCENT.. -15
1956
1957
1958
1959
1963
1964
1965
1966
1969
1970
1971
1972
1974
1975
1976
1977
1978
1979
1980
1981
1982
1984
1985
1988
1989
1990
1991
1992
1993
1994
1995
1996
1997
1998
1999
2001
2002
2003

47,196.60
4,105.00
16,541.06
668.56
18.00
520.00
4,631.00
126.37
12,502.99
395.87
595.00
279.00
20,933.98
119,759.61
17,902.00
1,712.00
17,378.00
4,878.00
38,794.04
1,017.00
1,475.00
158,135.22
39,869.71
1,170.11
2,677.45
23,387.00
51,555.00
424,824.23
7,293.25
1,060,360.12
846,562.36
69,429.47
1,379,250.62
1,310,019.29
43,011.56
142,678.00
355,960.00
340,447.80

46,050
3,972
15,865
635
16
470
4,139
112
10,624
332
491
227
16,483
92,673
13,606
1,277
12,706
3,494
27,204
698
988
100,828
24,759
666
1,477
12,473
26,561
210,945
3,485
486,412
372,109
29,152
551,976
498,162
15,487
45,542
106,252
94,398

54,276
4,721
19,022
769
21
598
5,326
145
14,378
455
684
321
24,074
137,724
20,587
1,969
19,985
5,610
44,613
1,170
1,696
181,856
45,850
1,346
3,079
26,895
59,288
488,548
8,387
1,219,414
973,547
79,844
1,586,138
1,506,522
49,463
164,080
409,354
391,514

6,568,060.27

2,832,746

7,553,269

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 0.0

0.00

 Attachment to Response to AG-2 Question No. 33(c)
Page 102 of 149
Spanos

SURVIVOR CURVE.. IOWA 70-R4
NET SALVAGE PERCENT.. -40
1941
1942
1949
1951
1953
1956
1958
1959
1960
1961
1962
1963
1964
1965
1966
1967
1969
1970
1971
1972
1973
1974
1975
1976
1977
1978
1979
1980
1981
1982
1984
1985
1986
1987
1988
1989
1990
1992
1994
1996
1997
1999
2000

411,762.97
1,388.10
360,382.06
20,488.00
20,743.65
19,906.16
986,158.80
17,524.00
16,344.36
630,143.58
252,963.20
276,404.84
49,946.80
56,872.95
72,558.00
140,496.00
503,586.20
2,450,234.08
1,216,527.88
272,111.12
977,622.68
226,225.99
192,029.00
465,378.15
971,068.22
5,770,262.52
105,174.77
12,532,292.00
138,335.27
6,445,195.05
9,911,845.74
4,464,870.00
1,888,194.87
1,778,980.00
11,777.06
1,632,118.38
238,275.00
44,670.00
0.01
108,099.00
1,549,505.00
106,700.00
30,847.86

507,621
1,700
417,972
23,295
23,075
21,367
1,031,518
18,088
16,638
632,538
250,231
269,329
47,919
53,711
67,406
128,329
443,860
2,119,943
1,032,596
226,451
797,155
180,573
149,975
355,364
724,421
4,201,882
74,716
8,674,878
93,238
4,225,509
6,131,507
2,678,038
1,097,041
999,790
6,393
854,897
120,187
20,807

576,468
1,943
497,439
27,724
27,462
25,429
1,227,636
21,527
19,801
752,800
297,806
320,535
57,030
63,923
80,222
152,728
528,249
2,522,999
1,228,919
269,505
948,715
214,905
178,489
422,928
862,152
5,000,769
88,921
10,324,197
110,965
5,028,888
7,297,266
3,187,202
1,305,617
1,189,876
7,608
1,017,435
143,038
24,763

7,096
959
1,579
2,440
152,986
3,007
3,081
129,401
56,342
66,432
12,896
15,699
21,359
43,966
176,772
907,329
474,220
111,451
419,957
101,811
90,352
228,601
497,344
3,077,599
58,324
7,221,012
82,704
3,994,385
6,579,318
3,063,616
1,337,856
1,300,696
8,880
1,267,531
190,547
37,775

12.01
13.15
14.38
16.33
17.70
18.39
19.10
19.81
20.54
21.28
22.03
22.78
23.55
24.33
25.93
26.74
27.56
28.39
29.23
30.09
30.95
31.82
32.70
33.59
34.48
35.39
36.30
37.22
39.07
40.01
40.95
41.90
42.86
43.81
44.78
46.71

591
73
110
149
8,643
164
161
6,532
2,743
3,122
585
689
907
1,807
6,817
33,932
17,207
3,926
14,367
3,384
2,919
7,184
15,209
91,622
1,692
204,041
2,278
107,318
168,398
76,571
32,670
31,043
207
28,932
4,255
809

41,900
570,224
35,061
9,526

49,866
678,639
41,727
11,337

101,473
1,490,668
107,653
31,850

50.62
51.60
53.57
54.56

2,005
28,889
2,010
584

 Attachment to Response to AG-2 Question No. 33(c)
Page 103 of 149
Spanos

SURVIVOR CURVE.. IOWA 70-R4
NET SALVAGE PERCENT.. -40
2001
2002
2003
2004
2005
2009
2010
2011
2012
2013
2014
2015

42,618.00
452,193.36
2,222,893.40
831,149.91
1,603.60
1,570,011.47
841,844.22
61,080.35
8,105,126.65
3,112,137.44
895,946.95
900,683.97

12,317
121,733
553,945
190,669
336
203,778
92,436
5,485
567,359
155,588
26,880
9,003

14,659
144,878
659,264
226,920
400
242,521
110,011
6,528
675,228
185,170
31,990
10,715

45,006
488,193
2,452,787
936,690
1,845
1,955,495
1,068,571
78,984
10,671,949
4,171,822
1,222,336
1,250,243

76,403,298.64

41,316,198

49,143,732

57,820,886

55.55
56.54
57.54
58.53
59.52
63.51
64.51
65.51
66.50
67.50
68.50
69.50

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 44.8

810
8,634
42,628
16,004
31
30,790
16,564
1,206
160,480
61,805
17,844
17,989
1,289,330
1.69

 Attachment to Response to AG-2 Question No. 33(c)
Page 104 of 149
Spanos

SURVIVOR CURVE.. IOWA 58-R2
NET SALVAGE PERCENT.. -75
1941
1942
1943
1944
1945
1946
1947
1948
1949
1950
1951
1952
1953
1954
1955
1956
1957
1958
1959
1960
1961
1962
1963
1964
1965
1966
1967
1968
1969
1970
1971
1972
1973
1974
1975
1976
1977
1978
1979
1980
1981
1982
1983

49,501.34
23,167.41
8,711.34
278.28
3,917.29
2,071.16
43,007.56
9,448.45
72,294.42
4,479.31
143,235.10
78,634.67
210,762.63
14,385.25
245,747.30
178,925.18
52,287.22
373,755.56
410,130.07
320,076.26
369,663.62
231,678.89
537,569.39
333,354.15
602,793.34
565,212.28
792,125.50
245,101.70
1,649,051.79
803,293.08
601,618.65
1,122,083.06
2,519,769.01
1,134,205.72
1,011,951.71
1,561,506.76
638,078.25
1,361,062.08
1,340,209.40
1,185,133.59
1,960,635.57
1,408,631.89
1,440,317.61

72,439
33,672
12,572
399
5,571
2,923
60,211
13,120
99,555
6,114
193,744
105,391
279,743
18,907
319,653
230,305
66,560
470,481
510,204
393,348
448,711
277,587
635,493
388,746
692,956
640,199
883,590
269,191
1,781,747
853,396
628,246
1,150,755
2,537,017
1,120,076
979,812
1,481,280
592,588
1,236,518
1,190,062
1,028,053
1,659,355
1,162,421
1,157,716

79,128
36,781
13,733
436
6,085
3,193
65,771
14,331
108,748
6,679
211,634
115,122
305,574
20,653
349,169
251,571
72,706
513,924
557,315
429,668
490,144
303,218
694,172
424,642
756,941
699,313
965,178
294,047
1,946,268
932,196
686,256
1,257,012
2,771,277
1,223,500
1,070,285
1,618,057
647,306
1,350,694
1,299,948
1,122,980
1,812,574
1,269,755
1,264,616

7,499
3,762
1,512
51
770
432
9,492
2,204
17,767
1,160
39,027
22,489
63,261
4,521
80,889
61,548
18,797
140,148
160,413
130,465
156,767
102,220
246,574
158,728
297,947
289,808
421,042
134,881
939,573
473,567
366,577
706,633
1,638,319
761,360
700,630
1,114,580
469,331
1,031,165
1,045,418
951,004
1,618,538
1,195,351
1,255,940

9.50
9.83
10.17
10.52
10.87
11.23
11.60
11.98
12.36
12.76
13.17
13.58
14.01
14.44
14.89
15.34
15.81
16.28
16.77
17.27
17.77
18.29
18.82
19.35
19.90
20.46
21.03
21.60
22.19
22.79
23.39
24.01
24.63
25.27
25.91
26.56
27.22
27.89
28.57
29.25
29.95
30.65
31.36

789
383
149
5
71
38
818
184
1,437
91
2,963
1,656
4,515
313
5,432
4,012
1,189
8,609
9,565
7,554
8,822
5,589
13,102
8,203
14,972
14,165
20,021
6,244
42,342
20,780
15,672
29,431
66,517
30,129
27,041
41,965
17,242
36,973
36,591
32,513
54,041
39,000
40,049

 Attachment to Response to AG-2 Question No. 33(c)
Page 105 of 149
Spanos

SURVIVOR CURVE.. IOWA 58-R2
NET SALVAGE PERCENT.. -75
1984
1985
1986
1987
1988
1989
1990
1991
1992
1993
1994
1995
1996
1997
1998
1999
2000
2001
2002
2003
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015

2,273,009.79
1,580,351.03
3,527,168.76
590,855.70
2,372,872.15
2,317,960.70
1,505,268.28
1,468,700.81
2,489,377.34
707,926.13
1,419,981.90
2,994,768.95
3,231,991.65
2,553,646.78
2,053,898.99
3,471,370.10
1,032,772.53
3,399,636.14
1,384,479.67
6,370,205.61
1,508,743.00
6,460,010.00
2,936,712.52
8,318,033.57
1,876,246.58
15,459,085.06
8,925,672.90
5,709,054.76
45,400,179.38
11,920,916.11
12,994,487.43
34,884,598.58

1,777,664
1,201,604
2,604,197
423,050
1,645,272
1,554,019
974,661
916,851
1,496,209
408,827
786,194
1,585,827
1,633,392
1,228,183
937,615
1,498,799
420,047
1,297,556
493,339
2,108,506
460,680
1,806,881
745,191
1,892,353
378,153
2,705,340
1,325,038
695,962
4,314,947
809,222
533,261
473,733

1,941,808
1,312,556
2,844,660
462,113
1,797,191
1,697,512
1,064,658
1,001,510
1,634,364
446,577
858,789
1,732,257
1,784,214
1,341,589
1,024,191
1,637,193
458,833
1,417,368
538,892
2,303,199
503,218
1,973,722
814,000
2,067,087
413,070
2,955,142
1,447,388
760,225
4,713,375
883,943
582,500
517,476

2,035,959
1,453,058
3,327,885
571,884
2,355,335
2,358,919
1,569,561
1,568,716
2,722,046
792,294
1,626,179
3,508,589
3,871,771
3,127,293
2,570,132
4,437,705
1,348,519
4,531,995
1,883,947
8,844,661
2,137,082
9,331,296
4,325,247
12,489,472
2,870,362
24,098,257
14,172,540
9,230,621
74,736,939
19,977,660
22,157,853
60,530,572

228,799,845.74

66,823,000

72,993,220

327,406,510

32.08
32.80
33.53
34.27
35.02
35.78
36.54
37.31
38.08
38.86
39.65
40.45
41.25
42.06
42.87
43.69
44.52
45.35
46.19
47.03
47.88
48.73
49.59
50.46
51.32
52.20
53.08
53.96
54.85
55.75
56.64
57.55

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 48.8

63,465
44,301
99,251
16,688
67,257
65,928
42,955
42,045
71,482
20,388
41,013
86,739
93,861
74,353
59,952
101,573
30,290
99,934
40,787
188,064
44,634
191,490
87,220
247,512
55,931
461,652
267,003
171,064
1,362,570
358,344
391,205
1,051,791
6,711,919
2.93

 Attachment to Response to AG-2 Question No. 33(c)
Page 106 of 149
Spanos

SURVIVOR CURVE.. IOWA 65-R3
NET SALVAGE PERCENT.. -75
1941
1942
1943
1944
1945
1946
1947
1948
1949
1950
1951
1952
1953
1954
1955
1956
1957
1958
1959
1960
1961
1962
1963
1964
1965
1966
1967
1968
1969
1970
1971
1972
1973
1974
1975
1976
1977
1978
1979
1980
1981
1982
1983

624,600.94
70,238.60
16,512.85
222.83
6,864.73
20,588.38
214,275.52
47,452.06
1,225,264.33
88,276.76
478,658.06
253,646.28
1,162,064.09
174,476.23
608,653.13
937,573.94
123,937.58
1,887,154.10
772,716.10
576,221.76
1,158,183.34
577,895.63
1,448,584.98
971,917.59
1,262,198.14
1,602,269.72
916,997.36
297,658.29
2,269,124.29
3,221,341.14
1,738,361.40
1,856,575.22
3,238,666.32
991,690.21
1,317,277.75
2,506,725.98
1,621,233.45
6,122,982.85
2,003,773.68
11,194,599.03
4,221,188.75
6,044,678.61
1,731,795.63

936,833
104,707
24,456
328
10,027
29,849
308,292
67,723
1,734,175
123,873
665,615
349,370
1,585,282
235,577
813,109
1,238,901
161,900
2,436,236
985,482
725,576
1,439,347
708,549
1,751,118
1,157,892
1,481,297
1,851,491
1,042,844
332,976
2,494,999
3,480,385
1,844,475
1,932,899
3,307,310
992,682
1,291,647
2,405,968
1,522,022
5,619,704
1,795,907
9,792,336
3,600,315
5,022,206
1,400,611

1,005,979
112,435
26,261
352
10,767
32,052
331,047
72,722
1,862,172
133,016
714,743
375,156
1,702,289
252,965
873,123
1,330,342
173,850
2,616,051
1,058,219
779,130
1,545,583
760,846
1,880,365
1,243,354
1,590,629
1,988,147
1,119,815
357,552
2,679,151
3,737,267
1,980,613
2,075,563
3,551,417
1,065,950
1,386,981
2,583,549
1,634,360
6,034,486
1,928,460
10,515,093
3,866,049
5,392,887
1,503,988

87,073
10,483
2,636
38
1,246
3,978
43,935
10,319
282,041
21,468
122,909
68,725
331,323
52,368
192,020
310,412
43,041
686,469
294,034
229,258
481,238
250,471
654,659
457,502
618,218
815,825
484,930
163,350
1,291,817
1,900,080
1,061,519
1,173,444
2,116,249
669,508
918,255
1,803,221
1,202,799
4,680,734
1,578,144
9,075,455
3,521,031
5,185,301
1,526,654

9.29
9.63
9.99
10.36
10.75
11.15
11.56
11.99
12.43
12.88
13.35
13.84
14.33
14.85
15.38
15.92
16.48
17.05
17.63
18.23
18.84
19.46
20.10
20.75
21.41
22.08
22.76
23.45
24.16
24.87
25.59
26.33
27.07
27.82
28.58
29.35
30.13
30.91
31.71
32.51
33.32
34.14
34.96

9,373
1,089
264
4
116
357
3,801
861
22,690
1,667
9,207
4,966
23,121
3,526
12,485
19,498
2,612
40,262
16,678
12,576
25,543
12,871
32,570
22,048
28,875
36,949
21,306
6,966
53,469
76,400
41,482
44,567
78,177
24,066
32,129
61,439
39,920
151,431
49,768
279,159
105,673
151,883
43,669

 Attachment to Response to AG-2 Question No. 33(c)
Page 107 of 149
Spanos

SURVIVOR CURVE.. IOWA 65-R3
NET SALVAGE PERCENT.. -75
1984
1985
1986
1987
1988
1989
1990
1991
1992
1993
1994
1995
1996
1997
1998
1999
2000
2001
2002
2003
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015

7,376,631.79
3,673,869.95
5,144,212.24
8,070,624.52
1,683,670.65
828,642.35
1,292,730.03
835,854.17
2,015,043.28
310,447.57
1,172,361.60
2,831,606.29
2,053,849.85
1,059,699.88
1,575,075.94
1,525,005.27
1,770,196.87
2,885,029.66
715,884.24
4,336,663.35
838,350.06
2,753,852.53
1,458,250.35
2,832,666.14
835,594.27
5,328,616.25
6,679,746.54
4,002,620.29
12,390,049.23
4,896,967.54
4,262,613.58
13,501,170.31

5,799,158
2,805,156
3,810,074
5,792,792
1,169,053
555,949
837,043
521,410
1,208,719
178,697
646,428
1,491,945
1,031,834
506,123
713,269
652,405
712,504
1,088,219
251,913
1,415,075
252,123
757,729
363,549
632,237
164,902
912,459
969,298
475,261
1,147,442
324,363
169,854
178,148

6,227,185
3,012,200
4,091,290
6,220,349
1,255,339
596,983
898,824
559,894
1,297,933
191,886
694,140
1,602,063
1,107,992
543,479
765,914
700,558
765,093
1,168,539
270,506
1,519,520
270,732
813,656
390,382
678,901
177,073
979,806
1,040,841
510,339
1,232,133
348,304
182,391
191,297

6,681,921
3,417,072
4,911,081
7,903,244
1,691,085
853,141
1,363,454
902,851
2,228,393
351,397
1,357,493
3,353,248
2,486,245
1,310,996
1,990,469
1,968,201
2,332,752
3,880,263
982,291
6,069,641
1,196,381
4,005,586
2,161,556
4,278,265
1,285,217
8,345,272
10,648,715
6,494,247
20,450,453
8,221,389
7,277,183
23,435,751

178,542,714.22

106,341,422

114,190,318

198,259,432

35.80
36.64
37.49
38.34
39.21
40.08
40.95
41.83
42.72
43.62
44.52
45.43
46.34
47.26
48.18
49.11
50.05
50.99
51.93
52.88
53.83
54.78
55.74
56.71
57.67
58.64
59.61
60.59
61.56
62.54
63.52
64.51

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 43.8

186,646
93,261
130,997
206,136
43,129
21,286
33,296
21,584
52,163
8,056
30,492
73,811
53,652
27,740
41,313
40,077
46,608
76,099
18,916
114,781
22,225
73,121
38,779
75,441
22,286
142,314
178,640
107,183
332,204
131,458
114,565
363,289
4,527,061
2.54

 Attachment to Response to AG-2 Question No. 33(c)
Page 108 of 149
Spanos

SURVIVOR CURVE.. IOWA 50-R4
NET SALVAGE PERCENT.. 0
1962
1969
1972
1973
1974
1980
1984
1997
1998
1999
2002
2003

16,102.50
629.49
1,023.52
66,872.27
1,183.38
26,278.29
275.00
318,959.12
449.82
702.00
3,451.41
12,833.46

14,212
514
798
51,264
891
17,496
165
116,675
156
230
926
3,193

15,803
572
887
57,005
991
19,455
183
129,741
173
256
1,030
3,550

300
57
137
9,867
192
6,823
92
189,218
277
446
2,421
9,283

448,760.26

206,520

229,646

219,114

5.87
9.14
11.00
11.67
12.35
16.71
19.92
31.71
32.67
33.64
36.58
37.56

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 28.7

51
6
12
846
16
408
5
5,967
8
13
66
247
7,645
1.70

 Attachment to Response to AG-2 Question No. 33(c)
Page 109 of 149
Spanos

SURVIVOR CURVE.. IOWA 40-R3
NET SALVAGE PERCENT.. 0
1962
1969
1972
1973
1974
1980
1982
1984
1988
1992
1997
2009
2015

13,218.53
87,624.88
15,875.19
78,405.34
136,383.31
204,862.86
13,871.63
2,212.12
123,767.49
116,241.28
313,023.53
55,822.59
11,994.57

12,062
75,576
13,268
64,743
111,186
151,496
9,842
1,499
75,282
61,928
134,757
8,820
147

13,219
87,625
15,875
78,405
136,383
204,863
13,872
2,210
110,986
91,298
198,667
13,003
217

2
12,781
24,943
114,357
42,820
11,778

1,173,303.32

720,606

966,623

206,680

12.89
15.67
18.69
22.78
33.68
39.51

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 23.6

816
1,335
5,020
1,271
298
8,740
0.74

 Attachment to Response to AG-2 Question No. 33(c)
Page 110 of 149
Spanos

SURVIVOR CURVE.. IOWA 70-R4
NET SALVAGE PERCENT.. 0
1941
1942
1943
1944
1945
1946
1947
1948
1949
1950
1951
1952
1953
1954
1955
1956
1957
1958
1959
1960
1961
1962
1963
1964
1965
1966
1967
1968
1969
1970
1971
1972
1973
1974
1975
1976
1977
1978
1979
1980
1981
1982
1984

373,772.94
41,173.38
911.00
850.00
2,100.00
3,262.00
4,434.00
3,258.00
4,314.00
59,904.00
18,663.00
27,550.00
33,233.00
24,267.00
40,298.35
21,633.00
19,771.00
27,040.00
19,357.00
33,627.00
18,106.00
10,562.32
21,516.00
20,398.00
35,563.00
5,187.00
19,695.00
15,350.00
41,542.00
24,874.00
46,508.00
16,301.00
8,970.00
43,465.00
27,337.00
6,205.00
15,472.00
17,820.00
31,886.00
10,670.00
1,808.00
61,168.00
14,670.00

329,133
36,027
792
734
1,799
2,774
3,739
2,724
3,574
49,147
15,157
22,134
26,406
19,060
31,277
16,586
14,967
20,203
14,272
24,452
12,982
7,463
14,975
13,979
23,990
3,442
12,850
9,841
26,154
15,372
28,197
9,690
5,224
24,781
15,250
3,384
8,244
9,269
16,180
5,276
870
28,644
6,482

373,773
41,173
911
850
2,100
3,262
4,434
3,258
4,314
59,904
18,663
27,550
33,233
24,267
40,298
21,633
19,771
27,040
19,357
33,627
18,106
10,562
21,338
19,919
34,184
4,905
18,310
14,023
37,267
21,904
40,178
13,807
7,444
35,311
21,730
4,822
11,747
13,207
23,055
7,518
1,240
40,815
9,236

178
479
1,379
282
1,385
1,327
4,275
2,970
6,330
2,494
1,526
8,154
5,607
1,383
3,725
4,613
8,831
3,152
568
20,353
5,434

21.28
22.03
22.78
23.55
24.33
25.12
25.93
26.74
27.56
28.39
29.23
30.09
30.95
31.82
32.70
33.59
34.48
35.39
36.30
37.22
39.07

8
22
61
12
57
53
165
111
230
88
52
271
181
43
114
137
256
89
16
547
139

 Attachment to Response to AG-2 Question No. 33(c)
Page 111 of 149
Spanos

SURVIVOR CURVE.. IOWA 70-R4
NET SALVAGE PERCENT.. 0
1985
1986
1987
1988
1989
1990
1991
1992
1993
1994
1995
1996
1997
1998
1999
2000
2001
2003
2004
2009
2010
2011
2012

33,531.00
779.00
16,266.00
4,886.00
7,350.00
38,364.00
12,981.00
5,140.00
38,715.00
23,233.00
54,744.00
143,362.00
100,670.04
11,034.00
28,534.63
5,450.00
1,400.00
113.00
74,362.56
58,265.05
3,796.63
22,282.80
209,177.61

14,366
323
6,530
1,894
2,750
13,822
4,499
1,710
12,345
7,083
15,923
39,691
26,462
2,744
6,697
1,202
289
20
12,185
5,402
298
1,429
10,459

20,470
460
9,305
2,699
3,919
19,695
6,411
2,437
17,590
10,093
22,689
56,556
37,706
3,910
9,543
1,713
412
28
17,362
7,697
425
2,036
14,903

13,061
319
6,961
2,187
3,431
18,669
6,570
2,703
21,125
13,140
32,055
86,806
62,964
7,124
18,992
3,737
988
85
57,001
50,568
3,372
20,247
194,275

2,168,929.31

1,125,619

1,458,105

710,824

40.01
40.95
41.90
42.86
43.81
44.78
45.74
46.71
47.68
48.66
49.64
50.62
51.60
52.59
53.57
54.56
55.55
57.54
58.53
63.51
64.51
65.51
66.50

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 51.4

326
8
166
51
78
417
144
58
443
270
646
1,715
1,220
135
355
68
18
1
974
796
52
309
2,921
13,823
0.64

 Attachment to Response to AG-2 Question No. 33(c)
Page 112 of 149
Spanos

SURVIVOR CURVE.. IOWA 60-R2.5
NET SALVAGE PERCENT.. -25
1940
1941
1945
1946
1947
1948
1949
1950
1951
1952
1953
1954
1955
1956
1957
1958
1959
1960
1961
1962
1963
1964
1965
1966
1967
1968
1969
1970
1971
1972
1973
1974
1975
1976
1977
1978
1979
1980
1981
1982
1983
1984
1985

238.90
503.83
56.00
11,183.46
4,642.00
2,742.00
5,131.61
13,026.82
5,204.70
5,293.78
202.30
16,676.06
20,624.35
18,449.76
12,480.07
26,992.10
11,277.90
16,138.04
16,723.37
28,657.49
39,606.77
33,481.83
27,875.09
20,756.17
29,960.66
38,002.13
52,376.58
14,931.52
76,589.72
44,762.96
54,026.62
63,345.57
48,572.11
26,172.81
72,116.85
67,478.67
95,377.11
158,265.95
59,640.98
103,233.38
13,444.28
68,778.00
8,631.87

255
534
58
11,505
4,744
2,782
5,168
13,019
5,159
5,203
197
16,099
19,718
17,462
11,690
25,007
10,331
14,608
14,953
25,302
34,507
28,773
23,613
17,327
24,630
30,750
41,694
11,684
58,895
33,796
40,036
46,044
34,597
18,261
49,235
45,056
62,234
100,829
37,065
62,543
7,929
39,461
4,812

233
488
53
10,524
4,339
2,545
4,727
11,909
4,719
4,759
180
14,726
18,037
15,973
10,693
22,875
9,450
13,362
13,678
23,144
31,565
26,320
21,600
15,850
22,530
28,128
38,139
10,688
53,873
30,914
36,622
42,118
31,647
16,704
45,037
41,214
56,927
92,231
33,904
57,210
7,253
36,096
4,402

66
142
17
3,455
1,464
882
1,688
4,375
1,787
1,858
73
6,119
7,743
7,089
4,907
10,865
4,647
6,811
7,226
12,678
17,943
15,532
13,244
10,095
14,921
19,375
27,332
7,976
41,864
25,040
30,911
37,064
29,068
16,012
45,109
43,134
62,294
105,601
40,647
71,832
9,552
49,876
6,388

8.83
9.11
10.29
10.62
10.95
11.30
11.66
12.03
12.42
12.82
13.23
13.66
14.11
14.57
15.04
15.53
16.03
16.55
17.08
17.62
18.18
18.75
19.34
19.93
20.54
21.16
21.79
22.44
23.09
23.76
24.43
25.11
25.81
26.51
27.23
27.95
28.68
29.42
30.17
30.92
31.69
32.46
33.24

7
16
2
325
134
78
145
364
144
145
6
448
549
487
326
700
290
412
423
720
987
828
685
507
726
916
1,254
355
1,813
1,054
1,265
1,476
1,126
604
1,657
1,543
2,172
3,589
1,347
2,323
301
1,537
192

 Attachment to Response to AG-2 Question No. 33(c)
Page 113 of 149
Spanos

SURVIVOR CURVE.. IOWA 60-R2.5
NET SALVAGE PERCENT.. -25
1986
1987
1988
1989
1990
1991
1992
1993
1994
1995
1997
1998
2000
2001
2002
2003
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015

50,245.96
80,691.35
9,583.49
21,186.00
89,521.00
232,064.00
133,283.06
45,318.28
559,184.42
40,486.86
163,072.85
81,469.76
66,743.00
270,942.78
141,181.00
212,582.75
15,786.36
134,777.18
137,673.95
632,246.14
39,332.05
376,899.45
1,748,743.89
662,257.08
736,752.19
793,055.08
1,147,920.41
662,124.22

27,185
42,330
4,866
10,399
42,430
105,975
58,561
19,128
226,120
15,655
57,212
27,106
19,773
75,244
36,589
51,153
3,503
27,348
25,327
104,321
5,736
47,739
187,618
58,361
50,495
38,989
33,964
6,481

24,867
38,720
4,451
9,512
38,812
96,938
53,567
17,497
206,839
14,320
52,333
24,795
18,087
68,828
33,469
46,791
3,204
25,016
23,167
95,426
5,247
43,668
171,620
53,384
46,189
35,665
31,068
5,928

37,940
62,144
7,528
16,970
73,089
193,142
113,037
39,151
492,142
36,289
151,508
77,042
65,342
269,850
143,007
218,937
16,529
143,455
148,925
694,882
43,918
427,456
2,014,310
774,437
874,751
955,654
1,403,833
821,727

10,718,796.73

2,467,173

2,256,794

11,141,702

34.03
34.82
35.63
36.44
37.25
38.08
38.91
39.74
40.59
41.44
43.16
44.03
45.78
46.67
47.56
48.45
49.35
50.26
51.17
52.08
53.00
53.92
54.85
55.77
56.71
57.64
58.58
59.53

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 48.4

1,115
1,785
211
466
1,962
5,072
2,905
985
12,125
876
3,510
1,750
1,427
5,782
3,007
4,519
335
2,854
2,910
13,343
829
7,928
36,724
13,886
15,425
16,580
23,964
13,804
230,057
2.15

 Attachment to Response to AG-2 Question No. 33(c)
Page 114 of 149
Spanos

SURVIVOR CURVE.. IOWA 54-R2
NET SALVAGE PERCENT.. -20
1930
1931
1934
1935
1937
1939
1940
1941
1942
1943
1944
1945
1946
1947
1948
1949
1950
1951
1952
1953
1954
1955
1956
1957
1958
1959
1960
1961
1962
1963
1964
1965
1966
1967
1968
1969
1970
1971
1972
1973
1974
1975
1976

15,555.43
729.35
1,455.51
3,176.82
2,952.72
12,360.53
20,935.23
36,231.37
8,428.73
3,934.21
10,947.83
22,095.81
19,892.98
32,135.31
137,378.61
128,858.17
96,435.66
49,455.90
225,772.23
322,649.00
363,371.02
255,309.63
500,562.62
173,267.34
326,971.75
183,873.55
320,917.58
436,362.45
716,323.13
714,897.33
540,627.11
768,070.75
775,871.38
690,294.92
866,204.61
1,454,949.96
447,206.14
1,025,259.41
897,923.42
1,284,663.07
1,279,217.89
1,018,426.59
900,410.18

17,280
806
1,579
3,427
3,147
13,011
21,898
37,656
8,702
4,036
11,152
22,356
19,981
32,043
135,944
126,538
93,929
47,774
216,240
306,301
341,729
237,836
461,739
158,213
295,436
164,341
283,550
381,091
617,949
609,093
454,607
637,161
634,666
556,530
687,957
1,137,445
344,050
775,785
667,656
938,369
917,061
716,292
620,678

16,212
756
1,481
3,215
2,952
12,207
20,544
35,328
8,164
3,786
10,463
20,974
18,746
30,062
127,540
118,716
88,122
44,821
202,872
287,366
320,604
223,133
433,195
148,432
277,172
154,182
266,021
357,532
579,748
571,439
426,504
597,772
595,431
522,126
645,428
1,067,129
322,781
727,827
626,382
880,360
860,369
672,011
582,308

2,455
119
266
597
591
2,626
4,578
8,150
1,950
935
2,674
5,541
5,126
8,500
37,314
35,914
27,601
14,526
68,055
99,813
115,441
83,239
167,480
59,489
115,194
66,466
119,080
166,103
279,840
286,438
222,249
323,913
335,615
306,228
394,018
678,811
213,866
502,484
451,126
661,236
674,692
550,101
498,184

4.01
4.30
5.17
5.46
6.04
6.63
6.93
7.23
7.54
7.84
8.16
8.47
8.80
9.13
9.47
9.81
10.17
10.53
10.90
11.28
11.68
12.08
12.49
12.91
13.34
13.78
14.24
14.70
15.18
15.66
16.16
16.67
17.19
17.72
18.26
18.82
19.38
19.95
20.54
21.13
21.74
22.35
22.98

612
28
51
109
98
396
661
1,127
259
119
328
654
582
931
3,940
3,661
2,714
1,379
6,244
8,849
9,884
6,891
13,409
4,608
8,635
4,823
8,362
11,300
18,435
18,291
13,753
19,431
19,524
17,281
21,578
36,069
11,035
25,187
21,963
31,294
31,035
24,613
21,679

 Attachment to Response to AG-2 Question No. 33(c)
Page 115 of 149
Spanos

SURVIVOR CURVE.. IOWA 54-R2
NET SALVAGE PERCENT.. -20
1977
1978
1979
1980
1981
1982
1983
1984
1985
1986
1987
1988
1989
1990
1991
1992
1993
1994
1995
1996
1997
1998
1999
2000
2001
2002
2003
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015

1,314,022.89
1,781,805.86
319,366.51
2,303,384.07
1,906,111.86
1,840,756.23
904,278.72
2,434,345.23
321,673.52
1,448,830.85
3,219,958.60
220,988.50
2,372,671.60
1,507,932.86
3,540,874.19
4,756,373.26
1,686,952.31
5,872,031.10
3,713,046.69
9,964.23
5,714,713.73
4,781,179.72
2,417,232.41
1,218,266.69
6,399,383.48
4,370,900.20
4,452,469.89
873,793.19
3,325,354.65
2,314,030.88
2,007,739.11
599,194.72
14,297,621.07
16,335,795.12
7,308,925.55
10,253,428.60
10,447,078.54
11,105,751.65
6,438,165.38

887,407
1,177,574
206,451
1,455,223
1,175,850
1,107,325
530,110
1,389,213
178,564
781,082
1,684,412
112,017
1,163,141
714,416
1,617,783
2,092,823
713,399
2,381,414
1,440,647
3,691
2,015,397
1,601,141
765,982
363,857
1,793,261
1,144,214
1,082,431
196,121
683,560
431,437
335,951
88,815
1,839,589
1,786,025
654,558
717,699
522,396
333,173
64,356

832,548
1,104,777
193,688
1,365,262
1,103,160
1,038,871
497,339
1,303,333
167,525
732,796
1,580,283
105,092
1,091,236
670,251
1,517,773
1,963,446
669,297
2,234,197
1,351,587
3,463
1,890,807
1,502,160
718,630
341,364
1,682,403
1,073,479
1,015,516
183,997
641,303
404,766
315,183
83,325
1,725,867
1,675,614
614,093
673,331
490,102
312,576
60,378

744,279
1,033,390
189,552
1,398,799
1,184,174
1,170,036
587,795
1,617,881
218,483
1,005,801
2,283,667
160,094
1,755,970
1,139,268
2,731,276
3,744,202
1,355,046
4,812,240
3,104,069
8,494
4,966,849
4,235,256
2,182,049
1,120,556
5,996,857
4,171,601
4,327,448
864,555
3,349,123
2,372,071
2,094,104
635,709
15,431,278
17,927,340
8,156,618
11,630,783
12,046,392
13,014,326
7,665,420

173,228,756.89

50,995,539

47,843,031

160,031,477

23.61
24.26
24.91
25.57
26.24
26.93
27.62
28.32
29.02
29.74
30.46
31.19
31.94
32.68
33.44
34.20
34.97
35.75
36.54
37.33
38.13
38.93
39.74
40.56
41.39
42.22
43.06
43.90
44.75
45.61
46.47
47.33
48.21
49.08
49.97
50.85
51.75
52.65
53.55

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 40.3

31,524
42,596
7,609
54,705
45,129
43,447
21,281
57,129
7,529
33,820
74,973
5,133
54,977
34,861
81,677
109,480
38,749
134,608
84,950
228
130,261
108,792
54,908
27,627
144,887
98,806
100,498
19,694
74,841
52,008
45,064
13,431
320,085
365,268
163,230
228,727
232,781
247,186
143,145
3,967,466
2.29

 Attachment to Response to AG-2 Question No. 33(c)
Page 116 of 149
Spanos

SURVIVOR CURVE.. IOWA 50-R1.5
NET SALVAGE PERCENT.. -50
1941
1942
1943
1944
1945
1946
1947
1948
1949
1950
1951
1952
1953
1954
1955
1956
1957
1958
1959
1960
1961
1962
1963
1964
1965
1966
1967
1968
1969
1970
1971
1972
1973
1974
1975
1976
1977
1978
1979
1980
1981
1982
1983

39,382.10
2,785.61
5,097.53
9,886.80
33,159.32
84,808.39
143,668.38
159,504.60
285,208.94
462,615.98
454,992.54
508,633.22
168,070.27
97,546.06
233,803.17
401,026.31
536,481.77
359,433.34
507,072.27
150,349.13
592,707.31
540,075.82
729,390.32
845,588.59
858,182.09
941,548.56
919,429.97
1,069,462.49
1,181,859.83
835,562.56
1,404,520.39
1,216,907.24
1,846,293.82
1,804,898.20
1,407,829.76
1,678,853.94
1,786,765.58
1,842,666.63
2,522,979.93
2,613,531.68
2,860,831.18
3,179,965.83
3,669,562.25

50,519
3,550
6,452
12,425
41,373
105,052
176,626
194,612
345,245
555,556
541,896
600,594
196,693
113,134
268,640
456,328
604,347
400,696
559,199
163,956
638,879
575,343
767,392
878,228
879,465
951,623
916,028
1,049,784
1,142,386
794,871
1,314,210
1,118,946
1,667,757
1,600,584
1,224,812
1,431,391
1,492,307
1,506,380
2,017,122
2,041,691
2,181,670
2,364,941
2,659,699

59,073
4,178
7,646
14,830
49,739
127,213
215,503
239,257
427,813
693,924
682,489
760,524
249,070
143,260
340,175
577,842
765,277
507,396
708,107
207,615
809,004
728,549
971,739
1,112,089
1,113,655
1,205,028
1,159,954
1,329,328
1,446,589
1,006,535
1,664,167
1,416,907
2,111,859
2,026,799
1,550,964
1,812,552
1,889,689
1,907,510
2,554,256
2,585,367
2,762,621
2,994,694
3,367,943

2,426
3,035
3,059
10,530
23,697
39,446
31,754
52,501
17,909
80,057
81,565
122,346
156,294
173,618
207,295
219,191
274,866
326,201
246,809
442,614
408,454
657,582
680,548
560,781
705,729
790,459
856,490
1,230,214
1,334,931
1,528,626
1,775,255
2,136,400

10.64
10.99
11.34
11.70
12.07
12.45
12.84
13.24
13.65
14.07
14.49
14.93
15.38
15.84
16.31
16.79
17.28
17.78
18.29
18.81
19.35
19.89
20.44
21.00
21.58
22.16
22.75
23.35
23.96
24.58
25.21
25.84

228
276
270
900
1,963
3,168
2,473
3,965
1,312
5,690
5,629
8,195
10,162
10,961
12,710
13,055
15,907
18,347
13,494
23,531
21,109
33,061
33,295
26,704
32,703
35,671
37,648
52,686
55,715
62,190
70,419
82,678

 Attachment to Response to AG-2 Question No. 33(c)
Page 117 of 149
Spanos

SURVIVOR CURVE.. IOWA 50-R1.5
NET SALVAGE PERCENT.. -50
1984
1985
1986
1987
1988
1989
1990
1991
1992
1993
1994
1995
1996
1997
1998
1999
2000
2001
2002
2003
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015

2,991,572.33
3,368,563.38
4,431,626.37
4,569,918.39
4,815,348.29
5,102,888.46
5,146,362.11
5,130,094.56
6,579,633.24
6,561,609.05
8,287,655.84
9,005,843.54
7,853,400.16
8,797,655.79
7,696,222.27
7,459,313.97
7,107,332.71
6,263,578.19
7,285,069.52
10,597,393.96
4,463,082.69
5,002,953.85
6,290,113.12
4,234,788.67
23,434,556.73
33,359,927.81
15,138,104.70
15,348,256.03
24,065,080.01
15,655,391.86
21,504,931.62
16,256,031.40

2,109,956
2,310,161
2,951,463
2,951,710
3,013,445
3,087,758
3,007,534
2,890,295
3,568,793
3,419,254
4,139,684
4,303,893
3,581,150
3,819,062
3,170,074
2,904,657
2,607,680
2,157,176
2,342,878
3,163,322
1,229,133
1,262,245
1,439,807
870,249
4,260,402
5,274,205
2,030,020
1,689,843
2,064,784
962,807
793,532
199,949

2,671,810
2,925,327
3,737,400
3,737,712
3,815,887
3,909,988
3,808,402
3,659,943
4,519,117
4,329,757
5,242,029
5,449,965
4,534,764
4,836,029
4,014,224
3,678,130
3,302,072
2,731,604
2,966,756
4,005,674
1,556,435
1,598,365
1,823,209
1,101,985
5,394,893
6,678,658
2,570,588
2,139,827
2,614,610
1,219,190
1,004,839
253,193

1,815,548
2,127,518
2,910,040
3,117,166
3,407,135
3,744,345
3,911,141
4,035,199
5,350,333
5,512,657
7,189,455
8,058,800
7,245,336
8,360,455
7,530,109
7,510,841
7,358,927
6,663,763
7,960,848
11,890,417
5,138,189
5,906,066
7,611,961
5,250,198
29,756,942
43,361,234
20,136,569
20,882,557
33,483,010
22,263,898
31,252,558
24,130,854

354,797,240.32

120,189,323

152,141,111

380,054,749

26.49
27.14
27.80
28.47
29.14
29.83
30.52
31.22
31.92
32.63
33.35
34.07
34.80
35.53
36.27
37.02
37.77
38.52
39.28
40.05
40.82
41.59
42.37
43.15
43.94
44.73
45.53
46.33
47.14
47.95
48.77
49.59

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 40.1

68,537
78,390
104,678
109,489
116,923
125,523
128,150
129,250
167,617
168,944
215,576
236,537
208,199
235,307
207,613
202,886
194,835
172,995
202,669
296,889
125,874
142,007
179,654
121,673
677,218
969,399
442,270
450,735
710,289
464,315
640,815
486,607
9,477,978
2.67

 Attachment to Response to AG-2 Question No. 33(c)
Page 118 of 149
Spanos

SURVIVOR CURVE.. IOWA 47-R1
NET SALVAGE PERCENT.. -30
1941
1942
1943
1944
1945
1946
1947
1948
1949
1950
1951
1952
1953
1954
1955
1956
1957
1958
1959
1960
1961
1962
1963
1964
1965
1966
1967
1968
1969
1970
1971
1972
1973
1974
1975
1976
1977
1978
1979
1980
1981
1982
1983

72,252.21
19,204.65
12,543.65
20,020.85
53,861.88
111,529.54
107,573.80
245,169.62
291,533.25
333,751.64
267,775.57
365,196.64
314,613.44
277,667.27
393,521.63
420,072.46
401,712.02
420,923.27
386,812.49
317,378.91
485,939.88
533,121.24
742,622.84
872,558.78
1,160,545.95
959,392.18
1,088,941.85
1,370,656.33
1,463,853.90
1,143,596.58
2,030,548.62
1,614,599.94
1,894,137.46
2,412,888.69
1,575,440.78
1,595,696.28
2,219,559.11
2,646,789.26
3,141,266.53
3,024,088.76
2,837,957.07
3,023,316.43
3,140,604.10

81,317
21,444
13,892
21,985
58,653
120,371
115,061
259,859
306,098
347,011
275,670
372,128
317,276
277,024
388,365
409,920
387,444
401,202
364,199
295,136
446,103
482,929
663,671
768,688
1,007,954
820,776
917,452
1,136,591
1,194,443
917,309
1,600,669
1,250,006
1,439,704
1,799,306
1,151,713
1,142,686
1,555,678
1,814,864
2,105,242
1,979,024
1,812,501
1,882,383
1,904,129

93,928
24,966
16,307
26,027
70,020
144,988
139,846
318,721
378,993
433,877
348,108
472,409
402,776
351,676
493,022
520,385
491,852
509,318
462,343
374,669
566,319
613,069
842,517
975,834
1,279,578
1,041,959
1,164,687
1,442,880
1,516,322
1,164,506
2,032,017
1,586,858
1,827,676
2,284,183
1,462,077
1,450,617
1,974,902
2,303,934
2,672,563
2,512,332
2,300,934
2,389,648
2,417,254

2,347
6,221
9,291
18,556
25,709
30,374
37,882
40,513
37,924
65,403
79,989
122,893
158,492
229,132
205,251
250,937
338,973
386,688
322,170
607,696
512,122
634,703
852,572
585,996
623,788
910,525
1,136,892
1,411,083
1,418,983
1,388,410
1,540,663
1,665,531

10.16
10.54
10.93
11.32
11.72
12.13
12.54
12.96
13.38
13.81
14.25
14.69
15.15
15.60
16.07
16.54
17.02
17.50
18.00
18.50
19.01
19.52
20.04
20.57
21.11
21.66
22.21
22.77
23.34
23.91
24.49
25.08

231
590
850
1,639
2,194
2,504
3,021
3,126
2,834
4,736
5,613
8,366
10,462
14,688
12,772
15,172
19,916
22,096
17,898
32,848
26,940
32,516
42,544
28,488
29,549
42,037
51,188
61,971
60,796
58,068
62,910
66,409

 Attachment to Response to AG-2 Question No. 33(c)
Page 119 of 149
Spanos

SURVIVOR CURVE.. IOWA 47-R1
NET SALVAGE PERCENT.. -30
1984
1985
1986
1987
1988
1989
1990
1991
1992
1993
1994
1995
1996
1997
1998
1999
2000
2001
2002
2003
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015

2,806,244.64
2,579,753.85
3,478,412.55
3,895,200.15
4,431,790.51
5,695,742.90
4,889,429.80
4,473,559.93
5,190,747.37
4,783,545.41
6,122,311.14
7,462,226.13
6,471,562.83
6,423,727.09
5,156,659.88
5,538,851.65
4,543,916.50
9,210,683.04
5,791,447.38
3,559,974.66
6,895,432.82
2,315,397.57
4,138,382.71
4,394,621.87
20,874,073.27
42,894,719.73
11,588,279.78
13,280,509.90
20,086,909.59
12,404,951.65
26,710,505.46
24,036,835.16

1,654,859
1,478,470
1,934,801
2,099,840
2,313,115
2,873,599
2,381,563
2,099,791
2,343,098
2,073,284
2,543,459
2,963,914
2,450,548
2,315,105
1,761,520
1,789,398
1,382,496
2,629,107
1,542,593
880,286
1,573,462
483,529
784,066
747,547
3,140,755
5,612,002
1,288,489
1,212,152
1,427,858
631,350
820,173
245,921

2,100,811
1,876,888
2,456,191
2,665,705
2,936,453
3,647,977
3,023,347
2,665,643
2,974,516
2,631,993
3,228,871
3,762,630
3,110,922
2,938,980
2,236,214
2,271,605
1,755,051
3,337,599
1,958,291
1,117,506
1,997,479
613,830
995,356
948,996
3,987,126
7,124,325
1,635,711
1,538,803
1,812,637
801,486
1,041,193
312,192

1,547,307
1,476,792
2,065,745
2,398,055
2,824,875
3,756,489
3,332,912
3,149,985
3,773,456
3,586,616
4,730,133
5,938,264
5,302,110
5,411,865
4,467,444
4,928,902
4,152,040
8,636,289
5,570,591
3,510,461
6,966,584
2,396,187
4,384,542
4,764,012
23,149,169
48,638,811
13,429,053
15,725,860
24,300,345
15,324,951
33,682,464
30,935,694

337,937,644.27

94,106,026

119,403,224

319,915,714

25.68
26.28
26.89
27.51
28.13
28.76
29.39
30.03
30.68
31.33
31.98
32.64
33.31
33.97
34.65
35.32
36.00
36.68
37.37
38.06
38.75
39.45
40.15
40.85
41.56
42.27
42.98
43.70
44.43
45.16
45.89
46.63

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 38.3

60,253
56,195
76,822
87,170
100,422
130,615
113,403
104,895
122,994
114,479
147,909
181,932
159,175
159,313
128,931
139,550
115,334
235,450
149,066
92,235
179,783
60,740
109,204
116,622
557,006
1,150,670
312,449
359,859
546,936
339,348
733,983
663,429
8,351,144
2.47

 Attachment to Response to AG-2 Question No. 33(c)
Page 120 of 149
Spanos

SURVIVOR CURVE.. IOWA 50-R4
NET SALVAGE PERCENT.. 0
1966
1967
1968
1973
1974
1976
1979
1980
1981
1982
1983
1986
1987
1989
1995
1998
2001
2003
2004
2005
2008
2009
2010
2011
2012
2014
2015

2,177.50
2,766.65
978.07
23,444.43
276,752.56
18,557.11
407,636.17
218,176.00
14.49
64,154.00
61,681.09
44,082.77
66,410.57
19,761.59
104,460.14
5,323.27
2,842.29
124,493.17
45,591.40
26,268.24
3,671.25
31,753.72
97,394.76
52,912.65
54,026.80
204,076.52
91,114.48

1,849
2,321
810
17,973
208,395
13,458
277,600
145,262
9
40,686
38,119
25,030
36,552
10,177
42,223
1,845
819
30,974
10,440
5,495
549
4,122
10,694
4,752
3,782
6,122
911

1,636
2,054
717
15,902
184,387
11,908
245,618
128,527
8
35,999
33,727
22,146
32,341
9,005
37,359
1,632
725
27,406
9,237
4,862
486
3,647
9,462
4,204
3,346
5,417
806

542
713
261
7,542
92,366
6,649
162,018
89,649
6
28,155
27,954
21,937
34,070
10,757
67,101
3,691
2,117
97,087
36,354
21,406
3,185
28,107
87,933
48,709
50,681
198,660
90,308

2,050,521.69

940,969

832,564

1,217,958

7.55
8.05
8.58
11.67
12.35
13.74
15.95
16.71
17.49
18.29
19.10
21.61
22.48
24.25
29.79
32.67
35.60
37.56
38.55
39.54
42.52
43.51
44.51
45.51
46.50
48.50
49.50

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 25.6

72
89
30
646
7,479
484
10,158
5,365
1,539
1,464
1,015
1,516
444
2,252
113
59
2,585
943
541
75
646
1,976
1,070
1,090
4,096
1,824
47,571
2.32

 Attachment to Response to AG-2 Question No. 33(c)
Page 121 of 149
Spanos

SURVIVOR CURVE.. IOWA 48-R2
NET SALVAGE PERCENT.. -20
1967
1968
1970
1971
1972
1973
1974
1975
1976
1977
1978
1979
1980
1981
1982
1983
1984
1985
1986
1987
1988
1989
1990
1991
1992
1993
1994
1995
1996
1997
1998
1999
2000
2001
2002
2003
2004
2005
2006
2007
2008
2009
2010

2,500.28
15,640.76
18,653.98
12,220.86
95,302.52
49,085.47
281,136.77
230,859.88
248,527.81
181,159.27
265,936.62
340,191.28
405,190.75
228,364.99
268,888.24
326,723.35
340,728.87
286,726.74
520,197.42
848,549.12
983,128.62
1,324,658.51
689,050.09
1,080,496.93
952,792.93
1,080,605.28
1,702,290.51
3,416,001.89
3,307,903.72
3,449,088.41
3,468,047.45
3,949,268.73
3,944,614.69
8,298,706.82
5,473,522.80
9,031,651.75
5,209,396.59
3,483,875.96
2,098,340.02
2,386,276.21
17,345,995.67
36,106,160.94
4,735,344.01

2,185
13,482
15,618
10,076
77,338
39,170
220,481
177,821
187,824
134,285
193,137
241,876
281,809
155,232
178,473
211,474
214,913
176,051
310,427
491,738
552,514
720,943
362,438
548,616
466,156
508,420
769,013
1,477,434
1,367,011
1,357,230
1,296,190
1,397,046
1,316,491
2,601,645
1,603,764
2,458,921
1,308,892
802,183
438,561
448,028
2,883,737
5,217,485
581,254

2,445
15,089
17,480
11,277
86,557
43,839
246,762
199,017
210,212
150,291
216,159
270,707
315,400
173,735
199,747
236,681
240,530
197,036
347,429
550,352
618,373
806,878
405,640
614,010
521,721
569,023
860,678
1,653,541
1,529,956
1,519,009
1,450,693
1,563,571
1,473,414
2,911,756
1,794,929
2,752,019
1,464,909
897,802
490,837
501,432
3,227,472
5,839,399
650,538

555
3,680
4,905
3,388
27,806
15,064
90,602
78,015
88,021
67,100
102,965
137,523
170,829
100,303
122,919
155,387
168,345
147,036
276,808
467,907
561,381
782,712
421,220
682,586
621,631
727,703
1,182,071
2,445,661
2,439,528
2,619,897
2,710,964
3,175,551
3,260,124
7,046,692
4,773,298
8,085,963
4,786,367
3,282,849
2,027,171
2,362,099
17,587,723
37,487,994
5,031,875

13.04
13.52
14.51
15.02
15.54
16.08
16.63
17.19
17.77
18.35
18.95
19.56
20.18
20.81
21.45
22.11
22.77
23.44
24.13
24.82
25.52
26.23
26.96
27.69
28.43
29.18
29.93
30.70
31.47
32.26
33.05
33.85
34.65
35.46
36.28
37.11
37.95
38.79
39.64
40.49
41.35
42.22
43.09

43
272
338
226
1,789
937
5,448
4,538
4,953
3,657
5,434
7,031
8,465
4,820
5,730
7,028
7,393
6,273
11,472
18,852
21,998
29,840
15,624
24,651
21,865
24,938
39,495
79,663
77,519
81,212
82,026
93,812
94,087
198,722
131,568
217,892
126,123
84,631
51,140
58,338
425,338
887,920
116,776

 Attachment to Response to AG-2 Question No. 33(c)
Page 122 of 149
Spanos

SURVIVOR CURVE.. IOWA 48-R2
NET SALVAGE PERCENT.. -20
2011
2012
2013
2014
2015

6,997,262.94
9,242,764.28
3,355,687.12
20,090,636.96
13,223,505.98

704,988
725,594
188,778
677,938
148,844

789,021
812,083
211,280
758,747
166,586

7,607,695
10,279,234
3,815,545
23,350,017
15,701,621

181,393,660.79

36,263,524

40,586,062

177,086,331

43.97
44.86
45.75
46.65
47.55

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 40.2

173,020
229,140
83,400
500,536
330,213
4,406,186
2.43

 Attachment to Response to AG-2 Question No. 33(c)
Page 123 of 149
Spanos

SURVIVOR CURVE.. IOWA 46-R2
NET SALVAGE PERCENT.. -5
1941
1942
1943
1944
1945
1946
1947
1948
1949
1950
1951
1952
1953
1954
1955
1956
1957
1958
1959
1960
1961
1962
1963
1964
1965
1966
1967
1968
1969
1970
1971
1972
1973
1974
1975
1976
1977
1978
1979
1980
1981
1982
1983

16,874.55
1,433.77
1,283.53
2,669.42
4,274.72
10,300.71
8,455.53
13,118.27
251,367.08
23,565.43
22,579.76
58,514.32
172,381.63
22,381.25
71,123.70
22,841.99
71,644.34
114,901.24
157,057.42
195,026.28
188,426.77
562,878.26
320,021.28
390,461.28
645,736.80
576,219.72
1,069,253.69
788,335.85
1,151,639.25
1,603,214.51
1,551,855.66
1,751,268.02
3,152,701.15
3,763,959.91
1,743,193.87
2,323,199.37
4,080,226.60
4,315,584.24
4,369,445.38
2,937,982.56
2,011,700.08
4,646,486.34
5,226,656.37

16,586
1,400
1,245
2,571
4,089
9,786
7,977
12,289
233,754
21,758
20,694
53,226
155,621
20,047
63,186
20,126
62,585
99,481
134,760
165,737
158,536
468,834
263,704
318,185
520,159
458,510
840,084
611,279
880,893
1,209,101
1,153,014
1,281,187
2,269,004
2,663,399
1,212,005
1,586,120
2,732,615
2,834,051
2,810,604
1,848,924
1,237,989
2,792,582
3,066,140

17,718
1,505
1,348
2,803
4,488
10,816
8,878
13,774
263,935
24,744
23,709
61,440
181,001
23,500
74,680
23,984
75,227
120,646
164,910
204,778
197,848
591,022
336,022
409,984
678,024
605,002
1,108,486
806,579
1,162,334
1,595,403
1,521,396
1,690,520
2,993,939
3,514,341
1,599,234
2,092,877
3,605,671
3,739,516
3,708,577
2,439,646
1,633,520
3,684,798
4,045,756

29
14,230
21,174
46,887
87,972
108,052
148,311
316,397
437,817
231,120
346,482
678,567
791,847
879,341
645,236
478,765
1,194,013
1,442,233

11.14
11.58
12.03
12.49
12.96
13.45
13.95
14.47
15.00
15.54
16.09
16.66
17.23
17.82
18.43
19.04
19.67
20.30

3
1,229
1,760
3,754
6,788
8,034
10,632
21,866
29,188
14,873
21,534
40,730
45,957
49,346
35,010
25,145
60,702
71,046

 Attachment to Response to AG-2 Question No. 33(c)
Page 124 of 149
Spanos

SURVIVOR CURVE.. IOWA 46-R2
NET SALVAGE PERCENT.. -5
1984
1985
1986
1987
1988
1989
1990
1991
1992
1993
1994
1995
1996
1997
1998
1999
2000
2001
2002
2003
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015

3,655,635.48
5,244,790.64
5,988,873.32
5,761,058.26
6,600,546.42
6,523,152.09
6,417,040.61
5,925,561.61
6,758,610.24
8,393,828.90
9,037,366.70
9,174,458.28
8,601,748.86
9,140,735.81
8,806,739.52
7,140,099.56
9,733,724.37
9,967,169.52
5,552,804.82
13,086,544.82
4,510,571.41
191,437.68
18,497,333.40
11,344,595.79
9,342,791.67
16,205,575.29
2,101,353.39
14,063,163.54
7,245,096.86
5,010,844.73
16,704,347.49
914,157.13

2,090,287
2,919,938
3,242,571
3,029,818
3,367,358
3,222,121
3,065,741
2,733,565
3,005,243
3,590,540
3,711,145
3,608,301
3,233,759
3,273,704
2,997,255
2,299,662
2,957,276
2,846,205
1,481,691
3,246,968
1,032,659
40,202
3,525,518
1,942,104
1,416,064
2,134,299
235,028
1,290,429
519,278
257,334
514,786
9,387

2,758,123
3,852,843
4,278,556
3,997,829
4,443,211
4,251,572
4,045,229
3,606,925
3,965,403
4,737,699
4,896,837
4,761,135
4,266,928
4,319,635
3,954,863
3,034,392
3,902,110
3,755,553
1,955,084
4,284,357
1,362,588
53,046
4,651,903
2,562,596
1,868,489
2,816,197
310,118
1,702,715
685,185
339,551
679,257
12,386

1,080,294
1,654,187
2,009,761
2,051,282
2,487,363
2,597,738
2,692,664
2,614,915
3,131,138
4,075,821
4,592,398
4,872,046
4,764,908
5,278,138
5,292,213
4,462,713
6,318,301
6,709,975
3,875,361
9,456,515
3,373,512
147,964
14,770,297
9,349,230
7,941,442
14,199,657
1,896,303
13,063,607
6,922,167
4,921,836
16,860,308
947,479

308,054,000.11

107,164,073

141,176,694

182,280,006

20.95
21.61
22.28
22.96
23.65
24.36
25.07
25.79
26.52
27.26
28.01
28.77
29.53
30.31
31.09
31.89
32.69
33.49
34.31
35.13
35.97
36.80
37.65
38.50
39.36
40.23
41.10
41.98
42.86
43.75
44.65
45.55

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 33.0

51,565
76,547
90,205
89,342
105,174
106,639
107,406
101,393
118,067
149,517
163,956
169,345
161,358
174,139
170,222
139,941
193,279
200,358
112,951
269,186
93,787
4,021
392,305
242,837
201,764
352,962
46,139
311,186
161,506
112,499
377,610
20,801
5,515,604
1.79

 Attachment to Response to AG-2 Question No. 33(c)
Page 125 of 149
Spanos

SURVIVOR CURVE.. IOWA 48-R1
NET SALVAGE PERCENT.. -25
1948
1949
1950
1951
1952
1953
1954
1955
1956
1957
1958
1959
1960
1961
1962
1963
1964
1965
1966
1967
1968
1969
1970
1971
1972
1973
1974
1975
1976
1977
1978
1979
1980
1981
1982
1983
1984
1985
1986
1987
1988
1989
1990

15,027.91
29,532.25
24,785.16
22,356.38
38,120.26
17,867.25
2,339.39
26,155.09
92,925.07
115,431.48
99,976.91
150,813.11
43,611.56
171,532.95
158,198.52
172,256.12
184,744.54
121,090.55
192,361.46
243,352.54
181,618.75
235,824.42
165,486.50
367,341.53
414,097.89
481,911.81
762,688.53
614,971.99
984,013.99
1,234,019.91
1,146,067.77
1,249,104.39
915,976.55
1,338,766.10
1,347,036.70
2,220,449.87
2,069,188.35
2,002,079.98
2,055,374.12
1,594,617.90
2,264,065.32
2,471,019.85
2,343,029.20

15,110
29,417
24,443
21,827
36,839
17,086
2,213
24,466
85,956
105,512
90,292
134,554
38,410
149,152
135,705
145,746
154,098
99,553
155,743
193,985
142,505
181,965
125,538
273,881
303,130
346,248
537,457
424,715
665,747
817,214
742,251
790,777
566,051
807,092
791,738
1,270,403
1,151,529
1,082,900
1,078,532
811,023
1,114,939
1,176,298
1,076,329

18,785
36,915
30,981
27,945
47,650
22,334
2,924
32,694
116,156
144,289
124,971
188,516
54,514
214,416
197,748
215,320
230,931
151,363
240,452
304,191
227,023
294,781
206,858
459,177
517,622
602,390
948,904
749,853
1,175,406
1,442,828
1,310,477
1,396,152
999,388
1,424,957
1,397,849
2,242,953
2,033,076
1,911,908
1,904,197
1,431,897
1,968,475
2,076,807
1,900,307

4,457
18,862
54,611
99,697
122,108
165,228
145,583
248,501
285,947
532,609
553,409
590,692
665,021
561,375
861,607
1,011,968
1,028,480

20.94
21.48
22.02
22.57
23.13
23.69
24.27
24.85
25.43
26.03
26.63
27.23
27.85
28.47
29.09
29.72
30.36

213
878
2,480
4,417
5,279
6,975
5,998
10,000
11,244
20,461
20,781
21,693
23,879
19,718
29,619
34,050
33,876

 Attachment to Response to AG-2 Question No. 33(c)
Page 126 of 149
Spanos

SURVIVOR CURVE.. IOWA 48-R1
NET SALVAGE PERCENT.. -25
1991
1992
1993
1994
1995
1996
1997
1998
1999
2000
2001
2002
2003
2004
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015

2,583,899.24
2,528,831.07
3,299,020.38
3,815,211.08
4,620,071.37
4,841,911.94
5,202,671.98
5,260,594.29
4,309,241.73
2,763,589.89
3,002,551.79
3,037,287.74
1,238,259.63
183,156.33
26,485.90
12,776.61
2,118,838.83
29,434.60
3,721,987.97
2,370,584.51
6,543,792.37
2,383,531.96
387,812.58
212,594.34

1,143,246
1,076,713
1,347,980
1,494,275
1,728,946
1,728,684
1,766,762
1,693,254
1,311,841
792,390
806,936
762,473
288,607
39,351
4,732
2,046
300,716
3,626
389,646
203,722
437,943
114,201
11,208
2,049

2,018,452
1,900,985
2,379,919
2,638,209
3,052,532
3,052,069
3,119,298
2,989,516
2,316,114
1,399,000
1,424,682
1,346,180
509,549
69,476
8,355
3,612
530,927
6,402
687,937
359,680
773,208
201,627
19,788
3,618

1,211,422
1,260,054
1,743,856
2,130,805
2,722,557
3,000,321
3,384,042
3,586,227
3,070,438
2,055,487
2,328,508
2,450,430
1,038,276
159,469
24,752
12,359
2,117,622
30,391
3,964,548
2,603,551
7,406,532
2,777,788
464,978
262,125

94,875,368.05

35,389,716

61,837,515

56,756,695

31.01
31.65
32.31
32.96
33.63
34.29
34.96
35.64
36.31
36.99
37.68
38.36
39.05
39.75
41.14
41.85
42.55
43.27
43.98
44.70
45.43
46.16
46.89
47.63

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 36.6

39,066
39,812
53,973
64,648
80,956
87,498
96,798
100,624
84,562
55,569
61,797
63,880
26,588
4,012
602
295
49,768
702
90,144
58,245
163,032
60,177
9,916
5,503
1,549,728
1.63

 Attachment to Response to AG-2 Question No. 33(c)
Page 127 of 149
Spanos

INTERIM SURVIVOR CURVE.. IOWA 28-L1
PROBABLE RETIREMENT YEAR.. 6-2020
NET SALVAGE PERCENT.. 0
1932
1940
1941
1942
1946
1947
1948
1949
1950
1951
1952
1953
1954
1955
1956
1957
1958
1959
1960
1961
1962
1963
1964
1965
1966
1967
1968
1969
1970
1971
1972
1973
1974
1975
1976
1977
1978
1979
1980
1981
1982
1983

256.00
84.00
4,518.76
5,492.19
143.78
189.09
45.02
43,375.25
124,031.65
199,643.26
162,426.96
94,499.81
145,402.38
148,806.24
124,118.11
195,127.61
282,971.70
226,794.66
248,850.24
259,542.58
261,810.20
311,696.72
331,941.96
415,091.60
351,607.77
333,427.36
410,706.62
499,200.25
447,345.28
590,644.41
729,034.35
772,207.56
1,506,963.97
632,224.04
987,281.74
1,674,450.03
1,244,419.61
1,565,320.23
635,533.38
564,719.97
710,972.55
1,300,880.56

246
78
4,156
5,033
130
171
41
38,959
111,136
178,451
144,896
84,128
129,183
131,988
109,863
172,423
249,626
199,806
218,859
227,951
229,532
272,887
290,194
362,342
306,465
290,162
356,999
433,186
387,687
510,966
629,791
666,091
1,297,270
543,321
846,979
1,433,798
1,063,406
1,334,780
540,966
479,526
602,151
1,098,685

256
84
4,519
5,492
144
189
45
43,375
124,032
199,643
162,427
94,500
145,402
148,806
124,118
195,128
282,972
226,795
248,716
259,048
260,845
310,114
329,782
411,773
348,273
329,746
405,701
492,281
440,575
580,672
715,707
756,959
1,474,243
617,441
962,524
1,629,396
1,208,475
1,516,870
614,764
544,943
684,296
1,248,567

134
495
965
1,583
2,160
3,319
3,335
3,681
5,006
6,919
6,770
9,972
13,327
15,249
32,721
14,783
24,758
45,054
35,945
48,450
20,769
19,777
26,677
52,314

3.36
3.39
3.43
3.46
3.49
3.52
3.55
3.58
3.60
3.63
3.65
3.68
3.70
3.72
3.75
3.77
3.79
3.81
3.83
3.85
3.86
3.88
3.90
3.92

40
146
281
458
619
943
939
1,028
1,391
1,906
1,855
2,710
3,602
4,099
8,726
3,921
6,532
11,825
9,385
12,584
5,381
5,097
6,840
13,345

 Attachment to Response to AG-2 Question No. 33(c)
Page 128 of 149
Spanos

INTERIM SURVIVOR CURVE.. IOWA 28-L1
PROBABLE RETIREMENT YEAR.. 6-2020
NET SALVAGE PERCENT.. 0
1984
1985
1986
1987
1988
1989
1990
1991
1992
1993
1994
1995
1996
1997
1998
1999
2000
2001
2002
2003
2004
2005
2006
2007
2009
2010
2011
2012
2013
2014
2015

903,737.50
905,107.05
1,114,093.39
1,151,398.41
1,221,553.73
1,177,299.65
1,495,505.99
1,553,505.30
2,274,577.07
1,203,958.30
1,483,991.15
1,888,267.11
1,888,549.61
2,294,899.50
1,983,536.61
1,775,684.50
2,191,344.41
2,290,366.87
2,298,261.99
1,530,578.47
507,456.67
85,774.69
3,478,669.70
323,978.33
1,810,784.76
1,444,365.45
567,383.89
1,706,714.95
4,944,354.99
49,712.95
123,596.02

761,381
760,127
932,830
960,543
1,014,952
974,510
1,232,746
1,274,061
1,856,032
976,579
1,196,364
1,512,275
1,500,264
1,808,289
1,548,488
1,371,983
1,673,749
1,724,898
1,704,897
1,115,042
361,979
59,624
2,347,372
210,719
1,067,983
792,307
283,045
745,459
1,760,685
12,428
12,235

865,248
863,823
1,060,086
1,091,580
1,153,411
1,107,452
1,400,917
1,447,868
2,109,231
1,109,804
1,359,572
1,718,579
1,704,929
2,054,975
1,759,732
1,559,148
1,902,081
1,960,208
1,937,479
1,267,156
411,360
67,758
2,667,600
239,465
1,213,677
900,393
321,658
847,154
2,000,877
14,124
13,904

38,490
41,284
54,007
59,818
68,143
69,848
94,589
105,637
165,346
94,154
124,419
169,688
183,621
239,924
223,805
216,536
289,263
330,159
360,783
263,422
96,097
18,017
811,070
84,513
597,108
543,972
245,726
859,561
2,943,478
35,589
109,692

66,212,808.46

49,538,154

56,280,887

9,931,921

3.93
3.95
3.96
3.98
4.00
4.01
4.02
4.04
4.05
4.07
4.08
4.09
4.11
4.12
4.13
4.14
4.15
4.17
4.18
4.20
4.22
4.25
4.27
4.30
4.34
4.37
4.39
4.41
4.43
4.44
4.46

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 4.3

9,794
10,452
13,638
15,030
17,036
17,418
23,530
26,148
40,826
23,134
30,495
41,489
44,677
58,234
54,190
52,303
69,702
79,175
86,312
62,720
22,772
4,239
189,946
19,654
137,582
124,479
55,974
194,912
664,442
8,016
24,595
2,326,567
3.51

 Attachment to Response to AG-2 Question No. 33(c)
Page 129 of 149
Spanos

SURVIVOR CURVE.. IOWA 28-L1
NET SALVAGE PERCENT.. 0
1941
1942
1943
1944
1945
1946
1947
1948
1949
1950
1951
1952
1953
1954
1955
1956
1957
1958
1959
1960
1961
1962
1963
1964
1965
1966
1967
1968
1969
1970
1971
1972
1973
1974
1975
1976
1977
1978
1979
1980
1981
1982
1983

41,613.33
61.84
12,390.22
6,909.10
20,694.86
30,134.62
62,014.51
67,799.84
12,850.15
18,892.89
17,696.32
28,242.39
10,013.44
15,256.87
33,172.75
34,207.47
20,350.16
23,825.97
49,498.70
35,876.50
39,613.81
47,064.07
56,092.75
48,988.23
75,388.21
83,377.48
66,872.27
99,293.50
107,597.36
90,708.21
125,934.75
51,409.73
112,116.72
181,179.13
94,918.39
24,100.09
162,837.51
229,932.64
174,665.38
199,272.43
197,888.25
293,082.24
134,941.75

37,794
56
11,103
6,147
18,285
26,432
53,997
58,599
11,024
16,086
14,947
23,663
8,322
12,576
27,119
27,720
16,345
18,967
39,051
28,035
30,658
36,071
42,570
36,794
56,029
61,312
48,626
71,385
76,471
63,690
87,390
35,216
75,839
120,937
62,476
15,648
104,157
144,940
108,417
121,698
118,873
173,127
78,315

31,527
47
9,262
5,128
15,253
22,049
45,044
48,883
9,196
13,419
12,469
19,739
6,942
10,491
22,622
23,124
13,635
15,822
32,576
23,387
25,575
30,090
35,511
30,693
46,739
51,146
40,563
59,549
63,791
53,130
72,900
29,377
63,264
100,884
52,117
13,053
86,887
120,908
90,440
101,519
99,163
144,421
65,330

10,086
15
3,128
1,781
5,442
8,086
16,971
18,917
3,654
5,474
5,227
8,503
3,071
4,766
10,551
11,083
6,715
8,004
16,923
12,490
14,039
16,974
20,582
18,295
28,649
32,231
26,309
39,744
43,806
37,578
53,035
22,033
48,853
80,295
42,801
11,047
75,951
109,025
84,225
97,753
98,725
148,661
69,612

2.57
2.74
2.91
3.09
3.26
3.44
3.62
3.80
3.98
4.16
4.35
4.54
4.73
4.92
5.11
5.31
5.51
5.71
5.91
6.12
6.33
6.54
6.75
6.97
7.19
7.41
7.64
7.87
8.10
8.34
8.57
8.82
9.06
9.31
9.57
9.82
10.09
10.35
10.62
10.90
11.18
11.46
11.75

3,925
5
1,075
576
1,669
2,351
4,688
4,978
918
1,316
1,202
1,873
649
969
2,065
2,087
1,219
1,402
2,863
2,041
2,218
2,595
3,049
2,625
3,985
4,350
3,444
5,050
5,408
4,506
6,188
2,498
5,392
8,625
4,472
1,125
7,527
10,534
7,931
8,968
8,831
12,972
5,924

 Attachment to Response to AG-2 Question No. 33(c)
Page 130 of 149
Spanos

SURVIVOR CURVE.. IOWA 28-L1
NET SALVAGE PERCENT.. 0
1984
1985
1986
1987
1988
1989
1990
1991
1992
1993
1994
1995
1997
1998
1999
2000
2001
2002
2003
2005
2006
2007
2008
2009
2010
2011
2012
2013

183,906.37
189,041.95
243,615.01
208,299.79
201,506.25
157,975.47
64,723.61
53,139.92
432,512.57
258,057.50
252,915.96
20,024.02
612,562.43
274,102.55
24,261.50
217,767.05
102,670.74
17,093.36
390,798.50
206,936.97
129,130.33
826,592.78
45,006.34
889,518.03
123,028.74
410,617.37
405,634.75
236,457.39

104,827
105,729
133,552
111,961
106,006
81,300
32,547
26,095
207,143
120,366
114,806
8,832
253,993
109,934
9,393
81,197
36,778
5,848
127,287
59,641
34,589
203,102
9,982
175,048
20,915
58,221
45,634
19,340

87,446
88,198
111,408
93,397
88,429
67,820
27,150
21,768
172,797
100,408
95,770
7,368
211,878
91,706
7,836
67,734
30,680
4,878
106,182
49,752
28,854
169,425
8,327
146,023
17,447
48,567
38,068
16,133

96,460
100,844
132,207
114,903
113,077
90,155
37,574
31,372
259,716
157,650
157,146
12,656
400,684
182,397
16,426
150,033
71,991
12,215
284,616
157,185
100,276
657,168
36,679
743,495
105,582
362,050
367,567
220,324

10,416,674.08

4,630,973

3,863,114

6,553,560

12.04
12.34
12.65
12.95
13.27
13.59
13.92
14.25
14.59
14.94
15.29
15.65
16.39
16.77
17.16
17.56
17.97
18.42
18.88
19.93
20.50
21.12
21.79
22.49
23.24
24.03
24.85
25.71

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 14.7

8,012
8,172
10,451
8,873
8,521
6,634
2,699
2,202
17,801
10,552
10,278
809
24,447
10,876
957
8,544
4,006
663
15,075
7,887
4,892
31,116
1,683
33,059
4,543
15,067
14,791
8,570
447,268
4.29

 Attachment to Response to AG-2 Question No. 33(c)
Page 131 of 149
Spanos

SURVIVOR CURVE.. IOWA 15-S2.5
NET SALVAGE PERCENT.. 0
2015

698,893.34

23,294

4,284

694,609

698,893.34

23,294

4,284

694,609

14.50

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 14.5

47,904
47,904
6.85

 Attachment to Response to AG-2 Question No. 33(c)
Page 132 of 149
Spanos

SURVIVOR CURVE.. IOWA 28-O1
NET SALVAGE PERCENT.. -10
1964
1965
1968
1970
1971
1972
1973
1974
1975
1976
1977
1978
1979
1980
1981
1982
1983
1984
1985
1986
1987
1988
1989
1990
1991
1992
1993
1994
1995
1996
1997
1998
1999
2000
2001
2003
2006
2007
2008

83.89
66.43
12.47
9,031.33
5,339.00
1,592.19
43,992.72
1,502.79
1,694.31
142,236.37
148,854.53
43,733.74
160,871.41
80,134.38
347,072.75
323,830.63
346,719.60
327,136.68
220,670.72
341,756.13
159,052.33
195,933.46
562,083.85
540,376.98
476,735.40
778,536.83
1,204,616.79
1,306,338.06
1,677,194.50
1,541,740.94
1,567,237.49
1,991,701.26
1,931,763.00
427,938.23
94,517.53
1,642.18
8,816.12
7,242.67
1,721.13

85
66
12
8,072
4,667
1,360
36,726
1,225
1,348
110,361
112,571
32,214
115,340
55,880
235,203
213,091
221,344
202,416
132,205
198,037
89,041
105,839
292,582
270,673
229,429
359,376
532,403
551,697
675,368
590,535
569,528
684,647
626,092
130,294
26,921
403
1,645
1,209
254

92
73
14
9,934
5,873
1,751
48,392
1,653
1,864
156,460
163,740
48,107
176,959
88,148
381,780
356,214
381,392
359,850
242,738
375,932
174,958
215,527
618,292
594,415
524,409
856,391
1,325,078
1,415,380
1,732,659
1,515,019
1,461,126
1,756,464
1,606,240
334,270
69,066
1,034
4,220
3,102
652

21,592
112,255
180,896
262,835
434,407
518,699
136,462
34,903
772
5,478
4,865
1,241

17.25
17.75
18.25
18.75
19.25
19.75
20.25
20.75
21.75
23.25
23.75
24.25

1,252
6,324
9,912
14,018
22,567
26,263
6,739
1,682
35
236
205
51

 Attachment to Response to AG-2 Question No. 33(c)
Page 133 of 149
Spanos

SURVIVOR CURVE.. IOWA 28-O1
NET SALVAGE PERCENT.. -10
2011
2012
2014

3,024.65
5,205.53
24,340.74

267
358
717

685
918
1,839

2,642
4,808
24,936

17,054,091.74

7,421,501

17,012,710

1,746,791

25.75
26.25
27.25

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 19.3

103
183
915
90,485
0.53

 Attachment to Response to AG-2 Question No. 33(c)
Page 134 of 149
Spanos

SURVIVOR CURVE.. IOWA 28-L0.5
NET SALVAGE PERCENT.. -10
1941
1942
1943
1944
1945
1946
1947
1948
1949
1950
1951
1952
1953
1954
1955
1956
1957
1958
1959
1960
1961
1962
1963
1964
1965
1966
1967
1968
1969
1970
1971
1972
1973
1974
1975
1976
1977
1978
1979
1980
1981
1982
1983

41,076.95
4,029.94
209.71
1,079.79
768.80
4,292.27
8,668.75
14,478.70
8,669.40
6,816.54
10,701.80
8,588.11
26,886.57
32,945.12
51,458.10
43,799.36
39,844.80
52,805.95
54,347.49
69,688.55
76,191.02
87,922.10
135,706.71
179,809.90
60,513.96
307,750.16
193,235.19
148,659.02
192,188.27
26,167.89
182,510.45
50,953.82
111,085.64
186,696.68
113,908.64
88,366.64
125,285.70
145,082.33
333,194.11
61,598.79
1,045,858.37
458,933.77
195,437.83

35,648
3,480
180
924
655
3,637
7,308
12,144
7,234
5,656
8,829
7,045
21,917
26,675
41,381
34,982
31,588
41,553
42,424
53,961
58,488
66,906
102,361
134,357
44,765
225,360
140,061
106,584
136,281
18,340
126,407
34,851
75,019
124,392
74,866
57,281
80,030
91,252
206,296
37,509
626,175
270,083
112,943

33,795
3,299
171
876
621
3,448
6,928
11,513
6,858
5,362
8,370
6,679
20,778
25,289
39,230
33,164
29,946
39,393
40,219
51,156
55,448
63,428
97,041
127,373
42,438
213,646
132,781
101,044
129,198
17,387
119,837
33,040
71,120
117,926
70,975
54,304
75,870
86,509
195,573
35,559
593,628
256,045
107,073

11,390
1,134
60
312
225
1,273
2,608
4,414
2,678
2,136
3,402
2,768
8,797
10,951
17,374
15,015
13,883
18,694
19,563
25,501
28,362
33,286
52,236
70,418
24,127
124,879
79,778
62,481
82,209
11,398
80,924
23,009
51,074
87,440
54,325
42,899
61,944
73,082
170,941
32,200
556,816
248,782
107,909

5.91
6.02
6.12
6.22
6.32
6.43
6.54
6.65
6.76
6.88
7.00
7.12
7.25
7.39
7.53
7.67
7.82
7.97
8.13
8.29
8.46
8.63
8.80
8.98
9.17
9.36
9.55
9.75
9.95
10.16
10.37
10.59
10.81
11.04
11.27
11.50
11.74
11.99
12.24
12.50
12.76
13.02
13.29

1,927
188
10
50
36
198
399
664
396
310
486
389
1,213
1,482
2,307
1,958
1,775
2,346
2,406
3,076
3,352
3,857
5,936
7,842
2,631
13,342
8,354
6,408
8,262
1,122
7,804
2,173
4,725
7,920
4,820
3,730
5,276
6,095
13,966
2,576
43,638
19,108
8,120

 Attachment to Response to AG-2 Question No. 33(c)
Page 135 of 149
Spanos

SURVIVOR CURVE.. IOWA 28-L0.5
NET SALVAGE PERCENT.. -10
1984
1985
1986
1988
1989
1990
1991
1992
1993
1994
1995
1996
1997
1998
1999
2000
2001
2002
2003
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015

870,408.00
930,846.77
625,183.91
178,175.94
1,122,501.63
740,066.91
587,593.72
417,023.52
969,302.45
1,528,527.70
600,454.85
933,533.18
1,287,919.21
912,390.42
2,614,443.57
2,971,656.54
2,434,615.19
1,985,302.15
5,111,538.88
1,903,209.90
396,543.57
318,362.08
42,005.95
2,808,783.88
8,358,582.52
17,156,153.84
4,672,804.56
6,355,945.80
2,005,001.28
15,925,692.98
4,245,037.71

493,431
517,454
340,413
92,887
571,517
367,790
284,628
196,761
444,768
680,959
259,484
390,587
520,641
355,576
980,879
1,070,539
838,800
652,027
1,592,403
559,266
109,049
81,172
9,836
594,760
1,572,893
2,803,779
640,660
696,637
162,259
800,760
75,040

467,784
490,558
322,719
88,059
541,811
348,673
269,834
186,534
421,650
645,565
245,997
370,285
493,580
337,094
929,896
1,014,895
795,201
618,136
1,509,634
530,197
103,381
76,953
9,325
563,846
1,491,139
2,658,046
607,360
660,428
153,825
759,139
71,140

489,665
533,373
364,983
107,935
692,941
465,401
376,519
272,192
644,583
1,035,815
414,503
656,601
923,131
666,535
1,945,992
2,253,927
1,882,876
1,565,696
4,113,059
1,563,334
332,817
273,245
36,882
2,525,816
7,703,302
16,213,723
4,532,725
6,331,112
2,051,676
16,759,123
4,598,401

95,997,822.30

22,095,483

20,947,022

84,650,583

13.57
13.85
14.14
14.73
15.04
15.35
15.67
15.99
16.32
16.66
17.00
17.35
17.71
18.08
18.45
18.83
19.23
19.64
20.07
20.52
21.00
21.51
22.04
22.61
23.21
23.84
24.51
25.21
25.94
26.72
27.55

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 22.1

36,084
38,511
25,812
7,328
46,073
30,319
24,028
17,023
39,497
62,174
24,383
37,844
52,125
36,866
105,474
119,699
97,913
79,720
204,936
76,186
15,848
12,703
1,673
111,712
331,896
680,106
184,934
251,135
79,093
627,213
166,911
3,837,892
4.00

 Attachment to Response to AG-2 Question No. 33(c)
Page 136 of 149
Spanos

SURVIVOR CURVE.. IOWA 50-S0
NET SALVAGE PERCENT.. -15
1941
1942
1949
1950
1952
1953
1955
1956
1957
1958
1960
1961
1962
1963
1965
1966
1967
1968
1969
1970
1971
1972
1973
1974
1975
1977
1979
1980
1981
1982
1983
1984
1985
1986
1988
1989
1990
1991
1992
1994
1995
1996
1997

20,925.95
561.26
227.20
2,473.03
2,144.06
807.17
9,134.26
269,264.00
13.55
157,902.06
3,486.27
43,899.38
361,103.33
15,228.70
93,255.64
311,293.37
30,369.85
6,845.65
177,919.99
931,480.68
153,987.54
381,891.85
20,525.49
29,934.37
106,055.99
99,499.44
99,458.52
80,159.37
1,181,126.82
243,932.20
381,705.99
181,632.11
1,317,694.72
718,386.14
588,128.55
6,204,960.03
764,131.71
278,237.87
761,913.37
800,609.07
3,291,747.62
926,707.45
199,853.77

19,425
516
194
2,090
1,771
659
7,284
212,113
11
121,300
2,609
32,411
263,031
10,939
65,076
214,076
20,571
4,564
116,790
601,587
97,787
238,472
12,595
18,038
62,763
56,663
54,375
42,921
618,568
124,888
190,948
88,689
627,658
333,432
258,365
2,647,346
316,351
111,607
295,630
289,284
1,143,981
309,270
63,893

16,086
427
161
1,731
1,467
546
6,032
175,651
9
100,449
2,161
26,840
217,816
9,059
53,889
177,276
17,035
3,779
96,714
498,175
80,977
197,479
10,430
14,937
51,974
46,923
45,028
35,543
512,237
103,420
158,124
73,443
519,764
276,115
213,952
2,192,269
261,970
92,422
244,811
239,556
947,332
256,107
52,910

7,979
218
100
1,113
999
382
4,472
134,003
7
81,138
1,848
23,644
197,453
8,454
53,355
180,711
17,890
4,093
107,894
573,028
96,109
241,697
13,174
19,488
69,990
67,501
69,349
56,640
846,059
177,102
280,838
135,434
995,585
550,029
462,396
4,943,435
616,781
227,552
631,389
681,144
2,838,178
809,607
176,922

9.64
10.03
12.85
13.25
14.08
14.49
15.33
15.75
16.18
16.60
17.46
17.90
18.33
18.77
19.66
20.10
20.55
21.01
21.46
21.92
22.39
22.85
23.32
23.80
24.27
25.24
26.23
26.72
27.23
27.74
28.25
28.77
29.29
29.82
30.90
31.45
32.00
32.56
33.13
34.29
34.89
35.49
36.10

828
22
8
84
71
26
292
8,508
4,888
106
1,321
10,772
450
2,714
8,991
871
195
5,028
26,142
4,292
10,578
565
819
2,884
2,674
2,644
2,120
31,071
6,384
9,941
4,707
33,991
18,445
14,964
157,184
19,274
6,989
19,058
19,864
81,346
22,812
4,901

 Attachment to Response to AG-2 Question No. 33(c)
Page 137 of 149
Spanos

SURVIVOR CURVE.. IOWA 50-S0
NET SALVAGE PERCENT.. -15
1998
1999
2000
2001
2002
2003
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015

143,057.78
434,929.92
448,594.83
1,061,063.69
161,504.46
1,738,444.06
317,371.37
1,183,971.00
646,597.22
1,088,091.67
4,422,984.30
2,633,686.17
1,160,979.54
3,125,052.54
6,334,518.20
2,888,311.90
1,775,868.42
5,860,718.68

43,696
126,543
123,915
277,235
39,746
400,642
68,105
235,006
117,635
179,437
653,098
342,248
129,507
290,380
466,221
154,785
58,408
66,050

36,185
104,790
102,614
229,579
32,914
331,772
56,398
194,609
97,414
148,592
540,830
283,416
107,245
240,464
386,077
128,177
48,368
54,696

128,331
395,379
413,270
990,644
152,816
1,667,439
308,579
1,166,958
646,173
1,102,713
4,545,602
2,745,323
1,227,881
3,353,346
6,898,619
3,193,382
1,993,881
6,685,130

56,676,361.14

13,473,198

11,157,166

54,020,649

36.72
37.35
37.99
38.64
39.30
39.98
40.67
41.37
42.09
42.83
43.58
44.35
45.15
45.96
46.80
47.67
48.57
49.51

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 39.2

3,495
10,586
10,878
25,638
3,888
41,707
7,587
28,208
15,352
25,746
104,305
61,901
27,196
72,962
147,406
66,989
41,052
135,026
1,378,746
2.43

 Attachment to Response to AG-2 Question No. 33(c)
Page 138 of 149
Spanos

SURVIVOR CURVE.. IOWA 33-R1.5
NET SALVAGE PERCENT.. -10
1954
1960
1962
1963
1966
1967
1970
1971
1973
1974
1977
1978
1979
1980
1981
1982
1983
1984
1985
1986
1987
1988
1989
1991
1992
1993
1994
1995
1996
1998
1999
2000

172.93
725.23
7,205.33
399.36
623.09
465.41
405.94
1,164.17
131.45
186.50
148.09
3,924.94
5,040.26
837.61
51,658.03
4,351.91
18,457.70
1,919.65
10,670.24
4,221.73
3,902.50
4,433.34
121,720.51
42,777.33
1,038.61
2,633.36
62,551.31
3,884.36
40,240.41
16,271.89
2,747.75
113,747.39

181
722
7,056
388
588
435
367
1,041
115
161
122
3,186
4,022
657
39,742
3,281
13,628
1,387
7,530
2,906
2,617
2,892
77,130
25,438
597
1,458
33,319
1,985
19,678
7,225
1,157
45,234

190
798
7,926
439
685
512
447
1,281
145
205
163
4,317
5,544
921
56,824
4,787
20,129
2,049
11,122
4,292
3,865
4,272
113,922
37,572
882
2,153
49,213
2,932
29,065
10,671
1,709
66,812

174
63
615
352
428
605
19,971
9,483
260
744
19,593
1,341
15,199
7,228
1,314
58,310

528,658.33

306,245

445,844

135,680

10.85
11.33
11.83
12.35
12.88
13.43
13.99
15.16
15.77
16.39
17.02
17.67
18.33
19.68
20.37
21.07

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 18.0

16
6
52
29
33
45
1,428
626
16
45
1,151
76
829
367
65
2,767
7,551
1.43

 Attachment to Response to AG-2 Question No. 33(c)
Page 139 of 149
Spanos

SURVIVOR CURVE.. 20-SQUARE
NET SALVAGE PERCENT.. 0
1979
1981
1992
1993
1994
1995
1996
1997
1998
1999
2000
2001
2002
2003
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015

139.70
3,659.24
98,424.92
97,780.00
146,869.00
380,370.00
218,919.78
273,690.39
217,728.76
197,525.05
3,589,975.52
163,226.00
188,528.48
250,973.01
149,260.52
164,091.73
99,011.55
312,121.99
181,323.81
591,964.52
56,433.78
106,713.53
415,596.78
396,657.69
865,497.68
831,276.04

140
3,659
98,425
97,780
146,869
380,370
213,447
253,164
190,513
162,958
2,782,231
118,339
127,257
156,858
85,825
86,148
47,030
132,652
67,996
192,388
15,519
24,011
72,729
49,582
64,912
20,782

140
3,659
98,425
97,780
146,869
380,370
217,218
257,636
193,879
165,837
2,831,381
120,430
129,505
159,629
87,341
87,670
47,861
134,995
69,197
195,787
15,793
24,435
74,014
50,458
66,059
21,149

1,702
16,054
23,850
31,688
758,595
42,796
59,023
91,344
61,920
76,422
51,151
177,127
112,127
396,178
40,641
82,279
341,583
346,200
799,439
810,127

9,997,759.47

5,591,584

5,677,517

4,320,242

0.50
1.50
2.50
3.50
4.50
5.50
6.50
7.50
8.50
9.50
10.50
11.50
12.50
13.50
14.50
15.50
16.50
17.50
18.50
19.50

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 9.9

1,702
10,703
9,540
9,054
168,577
7,781
9,080
12,179
7,285
8,044
4,872
15,402
8,970
29,347
2,803
5,308
20,702
19,783
43,213
41,545
435,890
4.36

 Attachment to Response to AG-2 Question No. 33(c)
Page 140 of 149
Spanos

SURVIVOR CURVE.. 5-SQUARE
NET SALVAGE PERCENT.. 0
2010
2011
2012
2013
2014
2015

206,886.83
3,765,841.71
4,343,857.39
3,274,129.88
4,786,100.58
10,578,786.40

206,887
3,389,258
3,040,700
1,637,065
1,435,830
1,057,879

206,887
3,765,842
4,343,857
2,361,534
2,071,245
1,526,034

912,596
2,714,856
9,052,752

26,955,602.79

10,767,619

14,275,399

12,680,204

2.50
3.50
4.50

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 4.0

365,038
775,673
2,011,723
3,152,434
11.69

 Attachment to Response to AG-2 Question No. 33(c)
Page 141 of 149
Spanos

SURVIVOR CURVE.. 4-SQUARE
NET SALVAGE PERCENT.. 0
2009
2010
2011
2012
2013
2014
2015

90,680.82
585,963.69
1,781,377.64
807,591.04
880,851.66
1,114,963.88
2,225,749.13

90,681
585,964
1,781,378
706,642
550,532
418,111
278,219

90,681
585,964
1,781,378
322,984
251,631
191,106
127,165

484,607
629,221
923,858
2,098,584

7,487,177.86

4,411,527

3,350,909

4,136,269

0.50
1.50
2.50
3.50

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 2.2

484,607
419,481
369,543
599,595
1,873,226
25.02

 Attachment to Response to AG-2 Question No. 33(c)
Page 142 of 149
Spanos

SURVIVOR CURVE.. IOWA 14-S2
NET SALVAGE PERCENT.. 0
1995
1997
1999
2000
2002
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014

13,338.44
92,023.03
245,293.25
19,170.48
20,067.63
25,658.90
21,485.44
48,222.98
53,416.01
37,375.96
72,524.72
207,041.78
20,712.34
137,303.90
66,621.85

11,871
78,483
198,688
15,076
14,692
16,147
12,630
26,144
26,288
16,339
27,404
65,071
5,119
24,421
7,138

13,338
92,023
245,293
19,170
20,068
25,659
21,485
48,223
53,416
35,017
58,732
139,459
10,971
52,339
15,298

2,359
13,793
67,583
9,741
84,965
51,324

1,080,256.71

545,511

850,491

229,766

7.88
8.71
9.60
10.54
11.51
12.50

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 10.8

299
1,584
7,040
924
7,382
4,106
21,335
1.97

 Attachment to Response to AG-2 Question No. 33(c)
Page 143 of 149
Spanos

SURVIVOR CURVE.. IOWA 16-L2.5
NET SALVAGE PERCENT.. 0
1986
1987
1990
1991
1992
1995
1996
1999
2000
2002
2004
2007
2008
2009
2010
2011
2012
2013
2014
2015

53,393.62
29,800.99
42,398.59
28,015.92
43,105.44
65,953.79
117,263.62
89,313.31
751,980.60
71,349.71
96,078.24
12,992.33
6,659.48
31,924.42
20,403.31
957,253.85
75,086.09
27,046.30
1,893,957.35
82,110.68

44,483
24,493
33,309
21,625
32,679
47,033
81,938
59,002
488,321
44,371
55,666
6,171
2,859
12,131
6,669
260,258
16,050
4,175
176,365
2,566

53,394
29,801
42,399
28,016
43,105
65,954
117,264
89,313
751,981
71,350
96,078
12,992
6,564
27,853
15,312
597,567
36,852
9,586
404,943
5,892

95
4,071
5,091
359,687
38,234
17,460
1,489,014
76,219

4,496,087.64

1,420,164

2,506,216

1,989,872

9.13
9.92
10.77
11.65
12.58
13.53
14.51
15.50

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 13.9

10
410
473
30,874
3,039
1,290
102,620
4,917
143,633
3.19

 Attachment to Response to AG-2 Question No. 33(c)
Page 144 of 149
Spanos

SURVIVOR CURVE.. 25-SQUARE
NET SALVAGE PERCENT.. 0
1992
1993
1994
1995
1996
1997
1998
1999
2003
2005
2007
2009
2011
2012
2014
2015

4,871.57
15,790.00
69,979.00
49,532.00
70,779.00
863.00
2,667.00
15,683.00
102,957.32
118,483.26
4,390.25
49,517.43
15,739.13
94,723.04
289,857.21
598,593.70

4,579
14,211
60,182
40,616
55,208
639
1,867
10,351
51,479
49,763
1,493
12,875
2,833
13,261
17,391
11,972

4,093
12,704
53,800
36,309
49,353
571
1,669
9,253
46,020
44,486
1,335
11,509
2,533
11,854
15,547
10,702

779
3,086
16,179
13,223
21,426
292
998
6,430
56,937
73,997
3,055
38,008
13,206
82,869
274,310
587,892

1,504,425.91

348,720

311,738

1,192,688

1.50
2.50
3.50
4.50
5.50
6.50
7.50
8.50
12.50
14.50
16.50
18.50
20.50
21.50
23.50
24.50

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 18.0

519
1,234
4,623
2,938
3,896
45
133
756
4,555
5,103
185
2,054
644
3,854
11,673
23,996
66,208
4.40

 Attachment to Response to AG-2 Question No. 33(c)
Page 145 of 149
Spanos

SURVIVOR CURVE.. 25-SQUARE
NET SALVAGE PERCENT.. 0
1991
1992
1993
1994
1995
1996
1997
1998
1999
2000
2001
2002
2003
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015

71,615.29
266,024.00
51,227.00
182,973.00
128,983.00
320,563.36
275,144.00
177,280.00
291,566.00
137,515.75
113,230.00
71,343.48
865,094.84
311,595.23
203,940.80
147,385.38
204,061.37
92,875.65
831,398.08
1,353,580.22
1,081,030.09
2,662,620.33
647,844.06
587,894.75
1,070,112.37

70,183
250,063
46,104
157,357
105,766
250,039
203,607
124,096
192,434
85,260
65,673
38,525
432,547
143,334
85,655
56,006
69,381
27,863
216,164
297,788
194,585
372,767
64,784
35,274
21,402

69,747
248,508
45,817
156,379
105,108
248,484
202,341
123,324
191,238
84,730
65,265
38,285
429,857
142,443
85,122
55,658
68,950
27,690
214,820
295,936
193,375
370,449
64,381
35,055
21,269

1,868
17,516
5,410
26,594
23,875
72,079
72,803
53,956
100,328
52,786
47,965
33,058
435,238
169,152
118,819
91,727
135,111
65,186
616,578
1,057,644
887,655
2,292,171
583,463
552,840
1,048,843

12,146,898.05

3,606,657

3,584,231

8,562,667

0.50
1.50
2.50
3.50
4.50
5.50
6.50
7.50
8.50
9.50
10.50
11.50
12.50
13.50
14.50
15.50
16.50
17.50
18.50
19.50
20.50
21.50
22.50
23.50
24.50

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 17.5

1,868
11,677
2,164
7,598
5,306
13,105
11,200
7,194
11,803
5,556
4,568
2,875
34,819
12,530
8,194
5,918
8,189
3,725
33,329
54,238
43,300
106,613
25,932
23,525
42,810
488,036
4.02

 Attachment to Response to AG-2 Question No. 33(c)
Page 146 of 149
Spanos

SURVIVOR CURVE.. IOWA 16-L5
NET SALVAGE PERCENT.. 0
1997
1999
2000
2003
2004
2005
2009
2010
2011
2012
2013
2014
2015

6,098.00
3,705.14
20,831.00
24,822.74
96,576.68
11,307.99
132,372.80
701,660.60
200,469.07
236,821.97
303,598.60
522,741.73
32,193.96

5,389
3,228
17,902
18,772
68,146
7,357
53,776
241,196
56,382
51,805
47,437
49,007
1,006

6,098
3,705
20,831
22,193
80,564
8,698
63,575
285,148
66,656
61,246
56,081
57,938
1,189

2,630
16,013
2,610
68,798
416,513
133,813
175,576
247,518
464,804
31,005

2,293,200.28

621,403

733,922

1,559,278

3.90
4.71
5.59
9.50
10.50
11.50
12.50
13.50
14.50
15.50

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 12.0

674
3,400
467
7,242
39,668
11,636
14,046
18,335
32,055
2,000
129,523
5.65

 Attachment to Response to AG-2 Question No. 33(c)
Page 147 of 149
Spanos

SURVIVOR CURVE.. IOWA 18-L3
NET SALVAGE PERCENT.. 0
1998
1999
2000
2001
2002
2003
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015

12,457.85
719,866.06
235,068.25
421,824.46
364,284.37
1,005,438.46
353,367.98
130,862.23
2,661,141.55
2,467,174.30
1,494,380.55
1,220,864.00
1,979,741.19
2,762,282.69
634,785.07
841,007.21
1,189,824.02
7,362,781.63

8,658
492,705
157,888
276,531
231,117
611,085
203,384
70,447
1,320,219
1,111,610
601,907
430,696
596,120
685,958
123,078
116,807
99,148
204,538

10,481
596,463
191,137
334,765
279,788
739,772
246,214
85,282
1,598,242
1,345,702
728,661
521,396
721,656
830,412
148,997
141,405
120,028
247,611

1,977
123,403
43,931
87,059
84,496
265,666
107,154
45,580
1,062,900
1,121,472
765,720
699,468
1,258,085
1,931,871
485,788
699,602
1,069,796
7,115,171

25,857,151.87

7,341,896

8,888,012

16,969,140

5.49
5.68
5.91
6.20
6.58
7.06
7.64
8.31
9.07
9.89
10.75
11.65
12.58
13.53
14.51
15.50
16.50
17.50

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 13.4

360
21,726
7,433
14,042
12,841
37,630
14,025
5,485
117,189
113,395
71,230
60,040
100,007
142,784
33,480
45,136
64,836
406,581
1,268,220
4.90

 Attachment to Response to AG-2 Question No. 33(c)
Page 148 of 149
Spanos

SURVIVOR CURVE.. 10-SQUARE
NET SALVAGE PERCENT.. 0
1998
1999
2000
2001
2002
2003
2004
2005
2006
2007
2008
2010
2011
2012
2013
2014
2015

55,121.82
21,147.52
6,604,605.34
26,921.72
287,671.98
570,618.36
318,932.87
11,795.73
157,786.36
140,698.85
579,287.48
3,948,503.15
134,632.83
152,535.52
176,438.80
370,049.66
6,452,905.12

55,122
21,148
6,604,605
26,922
287,672
570,618
318,933
11,796
149,897
119,594
434,466
2,171,677
60,585
53,387
44,110
55,507
322,645

20,009,653.11

11,308,684

55,122
21,148
6,604,605
26,922
287,672
570,618
318,933
11,796
2,2541,7986,53432,6589118036638354,8527,845,508

160,040
142,497
585,821
3,981,161
135,544
153,339
177,102
370,885
6,457,757

0.50
1.50
2.50
4.50
5.50
6.50
7.50
8.50
9.50

12,164,145

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 5.6

160,040
94,998
234,328
884,702
24,644
23,591
23,614
43,634
679,764
2,169,315
10.84

 Attachment to Response to AG-2 Question No. 33(c)
Page 149 of 149
Spanos

SURVIVOR CURVE.. 10-SQUARE
NET SALVAGE PERCENT.. 0
2012

5,875,508.03

2,056,428

497,906

5,377,602

5,875,508.03

2,056,428

497,906

5,377,602

6.50

COMPOSITE REMAINING LIFE AND ANNUAL ACCRUAL RATE, PERCENT .. 6.5

827,323
827,323
14.08

 KENTUCKY UTILITIES
DECOMMISSIONING COSTS RELATED TO GENERATING UNITS

ESTIMATED

TOTAL

TOTAL

ESTIMATED

DECOMMISSIONING

DECOMMISSIONING

DECOMMISSIONING

RETIREMENT

COSTS

COSTS

COSTS

TERMINAL

ESTIMATED

UNIT

YEAR

MW

($/KW)

(CURRENT $)

(FUTURE $)

RETIREMENTS

(1)

(2)

(3)

(4)

(5)=(3)*(4)

(6)

(7)

SYSTEM LABORATORY

2040

0

40

0

0

(3,981,926)

TRIMBLE COUNTY

2066

335

40

13,400,000

48,388,905

(590,869,790)

BROWN 1

2023

106

40

4,240,000

5,295,179

BROWN 2

2029

166

40

6,640,000

9,616,700

BROWN 3

2035

411

40

16,440,000

27,612,326

27,320,000

42,524,205

STEAM

TOTAL BROWN

(903,057,104)

GHENT 1

2034

493

40

19,720,000

32,313,516

GHENT 2

2034

490

40

19,600,000

32,116,882

GHENT 3

2037

454

40

18,160,000

32,045,330

GHENT 4

2038

487

40

19,480,000

35,233,981

TOTAL GHENT

76,960,000

131,709,709

(2,544,166,674)

TOTAL STEAM

117,680,000

222,622,819

(4,042,075,495)

260,000

506,428

(35,425,875)

260,000

506,428

(35,425,875)

HYDRO
DIX DAM

2041

26

10

TOTAL HYDRO

OTHER
CANE RUN

2055

660

20

13,200,000

36,328,914

(288,106,178)

HAEFLING 1, 2 AND 3

2020

36

10

360,000

417,490

(3,985,290)

PADDY'S RUN 13

2031

74

10

740,000

1,125,998

(27,330,118)

BROWN 5

2031

57

10

570,000

867,322

BROWN 6

2029

91

10

910,000

1,317,951

BROWN 7

2029

91

10

910,000

1,317,951

BROWN 8

2025

121

10

1,210,000

1,587,625

Attachment to Response to AG-2 Question No. 33(e)
Page 1 of 2
Spanos

 KENTUCKY UTILITIES
DECOMMISSIONING COSTS RELATED TO GENERATING UNITS

ESTIMATED

TOTAL

TOTAL

ESTIMATED

DECOMMISSIONING

DECOMMISSIONING

DECOMMISSIONING

RETIREMENT

COSTS

COSTS

COSTS

TERMINAL

ESTIMATED

UNIT

YEAR

MW

($/KW)

(CURRENT $)

(FUTURE $)

RETIREMENTS

(1)

(2)

(3)

(4)

(5)=(3)*(4)

(6)

(7)

BROWN 9

2031

121

10

1,210,000

1,841,158

BROWN 10

2031

121

10

1,210,000

1,841,158

BROWN 11

2026

121

10

1,210,000

1,627,315

BROWN GAS PIPELINE

2031

0

10

0

0

7,230,000

10,400,480

TOTAL BROWN

(229,538,287)

TRIMBLE COUNTY 5

2032

114

10

1,140,000

1,778,011

TRIMBLE COUNTY 6

2032

114

10

1,140,000

1,778,011

TRIMBLE COUNTY GAS PIPELINE

2034

10

0

0

TRIMBLE COUNTY 7

2034

101

10

1,010,000

1,655,003

TRIMBLE COUNTY 8

2034

101

10

1,010,000

1,655,003

TRIMBLE COUNTY 9

2034

101

10

1,010,000

1,655,003

TRIMBLE COUNTY 10

2034

101

10

1,010,000

1,655,003

6,320,000

10,176,034

(190,892,260)

27,850,000

58,448,916

(739,852,132)

TOTAL TRIMBLE COUNTY
TOTAL OTHER

Attachment to Response to AG-2 Question No. 33(e)
Page 2 of 2
Spanos

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 34
Responding Witness: Daniel K. Arbough
Q-34.

Refer to the response to AG-1-189. Provide similar comparable information as
projected for these periods:
a. 2017
b. 2018
c. Forecast Test Year ended 6/30/2018
A-34. Year
2017
2018
TYE 6/30/2018

107
$ 353,050,315
$ 415,023,299
$ 385,977,893

108
$ 13,826,679
$ 24,850,550
$ 16,512,205

Total
$ 366,876,993
$ 439,873,849
$ 402,490,098

The amounts above (as well as the amounts quoted in AG-1-189) exclude all
expenditures recovered through mechanisms other than base rates.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 35
Responding Witness: John P. Malloy
Q-35.

Refer to the response to AG-1-193. Does the Company have any meter
replacement programs that will affect meter plant lives? If so, identify and explain
fully (1) the programs and (2) how meter plant lives will be affected.

A-35.

The Company is evaluating options to provide a service similar to the AMS
proposal to our customers with MV-90 billable meters. The Company will
continue to utilize meter testing per Commission regulations to ensure the
continued proper operation of meters. The Company does not expect any changes
that would impact meter plant lives.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 36
Responding Witness: Daniel K. Arbough
Q-36.

Refer to the response to AG-1-205. Provide similar comparable information as
projected for these periods:
a. 2017
b. 2018
c. Forecast Test Year ended 6/30/2018

A-36.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 37
Responding Witness: Daniel K. Arbough
Q-37.

Refer to the response to AG-1-207. Provide similar comparable information as
projected for these periods:
a. 2017
b. 2018
c. Forecast Test Year ended 6/30/2018

A-37.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 38
Responding Witness: Daniel K. Arbough
Q-38. Refer to the response to AG-1-209. Provide similar comparable information as
projected for the Forecast Test Year ended 6/30/2018.
A-38. See attached.

 Attachment to Response to AG-2 Question No. 38
Page 1 of 3
Arbough
Expenses Billed By Affiliates to KU For Forecasted Test Year
For the 12 Months Ended 06/30/2018
a. Labor
b. Employee Benefits:
Overtime Payroll Taxes/Team Incentive Award
Pension, FAS 106 and FAS 112
Other Employee Benefits
Education/Training - Tuition Reimbursement
Misc Benefits Not On Burden Schedule
Total Employee Benefits
c. Employment Taxes - Not budgeted separately; included in part (b) above.
d. Outside Services
e. Promotional, Institutional and/or Corporate Advertising
f. Contributions:
g. Dues
American Coal Ash (ACAA)
Chartwell
Environmental Advocacy Group (Class of 85)
Coal Combustion Residuals (CCR)
Coal Utilization Research Council
Cross Cutting Issues Group (CCI)
Director Asset Mgmt - All UofL Research
Eastern Interconnection Planning Colaborative (EICP)
EEI Dues
IEEE Dues
Midwest Ozone Group Membership (MOG)
National Energy Policy Alliance (NEPA)
New Source Review (NSR)
North American Transmission Forum (NATF)
PIRA Energy Group
Southeastern Electric Exchange Membership Dues
Utility Air Regulatory Group Member (UARG)
Utility Solid Waste Activities Group (USWAG)
Utility Water Act Group-Membership (UWAG)
Waterways Council
Items below $4,000 and other items not budgeted in detail
Total Dues
h. Affiliate Owned/Leased Aircraft
i. Regulatory Costs
VSCC, Virginia Rate Case, Docket No. unknown at this time
Advertising, Docket No. unknown at this time
Docket No.'s 2016-00370, 2014-00371;KYPSC, 2014 and 2016 KY rate case
Required FERC Expenses, Docket No. unknown at this time
Total Regulatory Costs
j. Travel Costs
k. Lobbying or Politically Related Activities
l. Miscellaneous:
Audit - PCAOB Fees
Bank Service Fees
Cellular/Paging Services

$

Total
67,440,985
263,558
193,246
52,004,404
421,879
114,838
52,997,925
63,983,677
411,800
None
13,416
22,140
20,556
18,736
21,577
15,095
15,000
20,347
422,368
4,472
36,829
8,030
18,736
33,516
26,072
5,000
182,002
36,400
53,530
16,344
245,819
1,235,984
None
37,500
142,500
1,272,256
438,436
1,890,692
1,729,433
None
37,118
946,102
556,481

 Attachment to Response to AG-2 Question No. 38
Page 2 of 3
Arbough
Expenses Billed By Affiliates to KU For Forecasted Test Year
For the 12 Months Ended 06/30/2018
Chief Compliance Officer
Computer Custom Software or Services/Mtce - Nontaxable
Computer Hardware Mtce - Nontaxable
Computer Hardware Purchases - Taxable
Computer Prewritten Software or Upgrades/Updates Mtce - Taxable
Computer Software Purchases - Taxable
Credit Services
Depreciation
Education & Training - Course Fees
Facilities Expenses
Fees, Permits & Licenses
Financial Statement Reporting Software
Freight - Other
Hyperion Financial Management
Insurance Services
Internal Reporting
Investor Relations
IT Joint Initiatives - Non-Labor
Lease/Rental - Buildings
Lease/Rental - Other
Lease/Rental - Parking
Lease/Rental Vehicles And Equipment
Meals - Fully Deductible
Meals /Enter- Partially Deductible
O&M Non-labor Expenses for Jointly Owned Gas Turbines
Office and Administrative Services
Office of General Counsel
Pension/Investments
Postage
Power Transactions
Purchased Material - Coal
Purchased Material - Computer Hardware Purchases
Purchased Material - Computer Purchases And Supplies
Purchased Material - Computer Software Purchases
Purchased Material - Fuel Oil
Purchased Material - Gas
Purchased Material - Office Supplies/Equipment/Furniture
Purchased Material - Other
Purchased Material - Safety Supplies
Recruiting Expenses
Research and Development
Rights Of Way
Subscriptions
Telecommunications - Long Distance Calls
Telecommunications - Other
Transportation
UI Planner Software
Utilities

Total
58,208
63,075
225,691
(9,329)
4,480
286,844
7,891
763,147
1,327,144
254,030
2,871,508
3,514
129,418
9,676
9,968,150
172,549
210,283
78,947
1,652,791
381,392
7,306
10,932
713,496
314,907
22,057,909
6,077,668
470,722
251,821
3,015,775
44,046,036
14,417,119
101,916
2,205
65,830
475,444
117,161,160
269,203
1,271,731
177,850
67,073
3,724,500
124,236
506,218
60,675
1,609,878
196,689
10,486
49,870

 Attachment to Response to AG-2 Question No. 38
Page 3 of 3
Arbough
Expenses Billed By Affiliates to KU For Forecasted Test Year
For the 12 Months Ended 06/30/2018
Vehicles/Equipment
Wall Street Software
Total Miscellaneous

Grand Total

Total
415,626
37,440
237,710,829

427,401,326

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 39
Responding Witness: Gregory J. Meiman
Q-39.

Health and medical insurance. Refer to the response to AG-1-217.
a. Is the Company's cost of medical insurance projected for the Forecast Test
Year ended 6/30/2018 impacted by any provisions of the Affordable Health
Care Act (Obamacare)? If so, please explain.
b. Would the Company's cost of medical insurance projected for the Forecast
Test Year ended 6/30/2018 be impacted if Obamacare were to be repealed? If
not, explain fully why not. If so, identify, quantify and explain the impacts.

A-39.
a. No.
b. If repealed, the company would evaluate and decide whether to reduce
benefits or change eligibility that was required by the Affordable Care Act.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 40
Responding Witness: Valerie L. Scott
Q-40.

Refer to the response to AG-1-223.
a. In which customer class was the customer that was related to the $58,806
write off in 2015?
b. In which customer class was the customer that was related to the $582,856
write off in 2016?
c. In which customer class was the customer that was related to the $262,553
write off in 2016?
d. What were the circumstances related to each of these write-offs?

A-40.

Each write-off was related to an industrial customer that filed for bankruptcy.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 41
Responding Witness: Daniel K. Arbough / Valerie L. Scott
Q-41.

Refer to the response to AG-1-226.
a. Provide similar comparable information as projected for the Forecast Test
Year ended 6/30/2018.
b. Are any amounts for donations included in any of the 2015, 2016, or base year
Electric amounts? If so, identify the donation amounts.

A-41.
a. Injuries and damages expense for the forecasted test year is $4,319,943.
b. No amounts for donations are included in the 2015, 2016, or base year Electric
amounts.

 Response to AG-2 Question No. 42
Page 1 of 2
Scott/Wolfe
KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 42
Responding Witness: Valerie L. Scott / John K. Wolfe
Q-42.

Refer to the response to AG-1-230 re storm damage expense.
a. State the amount of storm cost amortization expense of regulatory assets in
each year.
b. What is the comparable amount of storm damage expense for the Forecast
Test Year ended 6/30/2018.
c. Show in detail how the amount identified in response to part b was derived.

A-42.

a.
2016
2015
2014
2013
2012
2011
2010
2009
2008
2007

Kentucky
$ 5,943,227
5,943,227
5,943,227
5,943,228
5,943,228
5,943,227
2,476,344
395,784
791,604
791,604

Virginia
$ 534,119
1,208,334
1,208,334
1,208,334
1,208,334
202,474
0
0
0
0

Total
$ 6,477,346
7,151,561
7,151,561
7,151,562
7,151,562
6,145,701
2,476,344
395,784
791,604
791,604

b. The storm damage expense for the forecast test year is $4,073,835.
c. The storm damage expense is estimated by using a 10 yr. historical average
(2006-2015), excluding major weather events, escalated by CPI. The test year
estimate is based on the 2006-2015 average monthly historical expenses,
excluding major weather events, escalated by CPI
factors.
This information was provided in response to KU PSC 2-30 (pages 2-6). A
typographical error was discovered that indicated a KU FERC account 426,

 Response to AG-2 Question No. 42
Page 2 of 2
Scott/Wolfe
which should have been KU FERC account 562. See attached file with the
corrected FERC account 562 on page 1 and 5.

 Attachment to Response to AG-2 Question No. 42(c)
Page 1 of 5
Wolfe
Kentucky Utilities Company
Case No. 2016-00370
10Year Average By FERC (CPI ADJUSTED)
Company
KU

KU Total
LG&E

LG&E Total
Grand Total

FERC
562
580
583
584
588
590
592
593
594
595
596
598
925
930
562
571
580
581
583
584
588
590
593
594
595
598
834
880
891
907
925
930
935

532.18
178,490.40
396,297.43
613.55
59,309.40
58,082.66
104,690.32
2,910,881.94
24,959.73
29,033.97
22.46
106,571.76
5,769.35
717.66
3,875,972.80
3,353.51
414,882.49
772,386.19
1,423.36
72,905.29
3,358,057.89
95,014.67
33,295.28
97,067.20
5,547.13
5,781.27
15,116.32
4,722.81
16,428.87
4,895,982.28
8,771,955.09

 Attachment to Response to AG-2 Question No. 42(c)
Page 2 of 5
Wolfe
Kentucky Utilities Company
Case No. 2016-00370
BP Amounts by FERC (CPI ADJUSTED)
Company FERC
KU
562
580
583
584
588
590
592
593
594
595
596
598
925
930
KU Total
LG&E
562
571
580
581
583
584
588
590
593
594
595
598
834
880
891
907
925
930
935
LG&E Total
Grand Total

2017
547.86
183,749.09
407,973.16
631.63
61,056.78
59,793.89
107,774.71
2,996,642.41
25,695.09
29,889.37
23.12
109,711.58
5,939.32
738.80
3,990,166.80
3,452.31
427,105.76
795,142.25
1,465.29
75,053.23
3,456,993.06
97,813.99
34,276.23
99,927.00
5,710.56
5,951.60
15,561.68
4,861.95
16,912.90
5,040,227.82
9,030,394.62

2018
563.57
189,020.58
419,677.30
649.75
62,808.41
61,509.29
110,866.60
3,082,611.66
26,432.25
30,746.85
23.78
112,859.04
6,109.71
760.00
4,104,638.80
3,551.36
439,358.80
817,953.71
1,507.33
77,206.40
3,556,169.09
100,620.13
35,259.56
102,793.76
5,874.38
6,122.34
16,008.12
5,001.43
17,398.10
5,184,824.52
9,289,463.32

CPI ADJUSTMENT TO
ESCALATE FOR BP

2021
2020
2019
2018

1.1434
1.1138
1.0885
1.0590

2017
2016

1.0295
1.0084

2019
579.29
194,292.07
431,381.45
667.87
64,560.04
63,224.69
113,958.50
3,168,580.91
27,169.40
31,604.33
24.45
116,006.50
6,280.10
781.20
4,219,110.80
3,650.40
451,611.83
840,765.17
1,549.36
79,359.56
3,655,345.12
103,426.27
36,242.89
105,660.52
6,038.21
6,293.09
16,454.57
5,140.92
17,883.31
5,329,421.22
9,548,532.02

2020
592.76
198,810.49
441,413.58
683.40
66,061.43
64,695.03
116,608.70
3,242,268.84
27,801.25
32,339.32
25.01
118,704.33
6,426.15
799.36
4,317,229.65
3,735.29
462,114.43
860,317.85
1,585.40
81,205.13
3,740,353.15
105,831.53
37,085.75
108,117.74
6,178.64
6,439.44
16,837.23
5,260.47
18,299.20
5,453,361.25
9,770,590.90

2021
608.48
204,081.98
453,117.73
701.52
67,813.06
66,410.43
119,700.60
3,328,238.09
28,538.40
33,196.80
25.68
121,851.79
6,596.54
820.56
4,431,701.65
3,834.33
474,367.47
883,129.31
1,627.43
83,358.30
3,839,529.18
108,637.67
38,069.09
110,984.50
6,342.46
6,610.18
17,283.67
5,399.95
18,784.41
5,597,957.95
10,029,659.60

 Kentucky Utilities Company
Case No. 2016-00370
Monthly Amounts for Budget Entry
2017
Jan
Feb
Mar
Apr
May
Jun
Jul
Aug
Sep
Oct
Nov
Dec
Total
10yr monthly avg
0.085829392 0.145008982 0.075802634 0.103345187 0.096084097 0.100804414 0.158119084 0.104881833 0.01683095 0.036444172
0.02890031 0.047948946
47.02
79.44
41.53
56.62
52.64
55.23
86.63
57.46
9.22
19.97
15.83
26.27
15,771.07
26,645.27
13,928.66
18,989.58
17,655.37
18,522.72
29,054.24
19,271.94
3,092.67
6,696.58
5,310.41
8,810.58
183,749.09
35,016.09
59,159.77
30,925.44
42,162.06
39,199.73
41,125.49
64,508.34
42,788.97
6,866.58
14,868.24
11,790.55
19,561.88
407,973.16
54.21
91.59
47.88
65.28
60.69
63.67
99.87
66.25
10.63
23.02
18.25
30.29
631.63
5,240.47
8,853.78
4,628.26
6,309.92
5,866.59
6,154.79
9,654.24
6,403.75
1,027.64
2,225.16
1,764.56
2,927.61
61,056.78
5,132.07
8,670.65
4,532.53
6,179.41
5,745.24
6,027.49
9,454.55
6,271.29
1,006.39
2,179.14
1,728.06
2,867.05
59,793.89
9,250.24
15,628.30
8,169.61
11,138.00
10,355.44
10,864.17
17,041.24
11,303.61
1,813.95
3,927.76
3,114.72
5,167.68
107,774.71
257,199.99
434,540.06
227,153.39
309,688.57
287,929.68
302,074.78
473,826.35
314,293.35
50,436.34
109,210.15
86,603.90
143,685.84
2,996,642.41
2,205.39
3,726.02
1,947.76
2,655.46
2,468.89
2,590.18
4,062.88
2,694.95
432.47
936.44
742.60
1,232.05
25,695.09
2,565.39
4,334.23
2,265.69
3,088.92
2,871.89
3,012.98
4,726.08
3,134.85
503.07
1,089.29
863.81
1,433.16
29,889.37
1.98
3.35
1.75
2.39
2.22
2.33
3.66
2.42
0.39
0.84
0.67
1.11
23.12
9,416.48
15,909.16
8,316.43
11,338.16
10,541.54
11,059.41
17,347.49
11,506.75
1,846.55
3,998.35
3,170.70
5,260.55
109,711.58
509.77
861.26
450.22
613.80
570.67
598.71
939.12
622.93
99.96
216.45
171.65
284.78
5,939.32
63.41
107.13
56.00
76.35
70.99
74.47
116.82
77.49
12.43
26.93
21.35
35.42
738.80
342,473.67
578,610.17
302,465.23
145,418.36
115,317.09
191,324.34
3,990,167.80
412,364.64
383,391.67
402,226.53
630,921.68
418,496.11
67,158.31
296.31
500.62
261.69
356.78
331.71
348.01
545.88
362.09
58.11
125.82
99.77
165.53
3,452.31
36,658.23
61,934.17
32,375.74
44,139.33
41,038.07
43,054.15
67,533.57
44,795.64
7,188.60
15,565.52
12,343.49
20,479.27
427,105.76
68,246.58
115,302.77
60,273.88
82,174.13
76,400.53
80,153.85
125,727.16
83,395.98
13,383.00
28,978.30
22,979.86
38,126.23
795,142.25
125.76
212.48
111.07
151.43
140.79
147.71
231.69
153.68
24.66
53.40
42.35
70.26
1,465.29
6,441.77
10,883.39
5,689.23
7,756.39
7,211.42
7,565.70
11,867.35
7,871.72
1,263.22
2,735.25
2,169.06
3,598.72
75,053.23
296,711.61
501,295.04
262,049.18
357,263.60
332,162.06
348,480.16
546,616.57
362,575.77
58,184.48
125,987.25
99,908.17
165,759.17
3,456,993.06
8,395.32
14,183.91
7,414.56
10,108.61
9,398.37
9,860.08
15,466.26
10,258.91
1,646.30
3,564.75
2,826.85
4,690.08
97,813.99
2,941.91
4,970.36
2,598.23
3,542.28
3,293.40
3,455.19
5,419.73
3,594.95
576.90
1,249.17
990.59
1,643.51
34,276.23
8,576.67
14,490.31
7,574.73
10,326.97
9,601.40
10,073.08
15,800.37
10,480.53
1,681.87
3,641.76
2,887.92
4,791.39
99,927.00
490.13
828.08
432.88
590.16
548.69
575.65
902.95
598.93
96.11
208.12
165.04
273.82
5,710.56
100.17
216.90
172.00
285.37
5,951.60
510.82
863.04
451.15
615.07
571.85
599.95
941.06
624.21
1,335.65
2,256.58
1,179.62
1,608.22
1,495.23
1,568.69
2,460.60
1,632.14
261.92
567.13
449.74
746.17
15,561.68
417.30
705.03
368.55
502.46
467.16
490.11
768.77
509.93
81.83
177.19
140.51
233.13
4,861.95
1,451.62
2,452.52
1,282.04
1,747.87
1,625.06
1,704.89
2,674.25
1,773.86
284.66
616.38
488.79
810.96
16,912.90
432,599.69
730,878.30
382,062.54
520,883.29
484,285.74
508,077.21
796,956.20
528,628.33
84,831.82
183,686.93
145,664.15
241,673.61
5,040,227.82
1.00
10Yr Monthly avg

0.057638486
Jan

0.104122247 0.083252597 0.085830919 0.110687585 0.096977645
0.20947868 0.092400201 0.06041718 0.035243372 0.024408515 0.039542571
Feb
Mar
Apr
May
Jun
Jul
Aug
Sep
Oct
Nov
Dec
Total

2016
3996.22
11,774.85

5937.24
8,241.68

4567.11
9,361.55

5423.43
6,345.48

6041.55
10,277.98

16841.11
1,681.61

4324.32
24,729.92

7881.49
11,390.45

10313.34
-

8032.42
-

4540.85
769.56

21276.93
-

99176.01
84,573.08

118010.13
139,189.86

95861.09
287,070.00

119990.51
105,055.97

108800.64
180,232.68

114518.06
173,411.62

107514.78
194,560.00

112373.56
361,452.79

108136.56
206,156.79

102045.31
-

111317.06
-

107259.14
-

113826.38
29,859.46

1319653.22
1,676,989.19

3996.22
32,662.01

5937.24
52,074.53

4567.11
27,808.63

5423.43
38,715.90

6041.55
34,996.52

16841.11
26,213.04

4324.32
63,209.25

7881.49
36,914.15

10313.34
-

8032.42
7,533.10

4540.85
7,802.64

21276.93
-

99176.01
327,929.75

180726.29
115,985.32

159161.91
275,836.71

209193.24
52,855.94

99682.44
192,594.11

176533.19
119,676.86

144727.56
203,752.60

95162.56
451,454.01

221801.27
140,774.50

123171.53
-

192283.67
-

135860.18
-

125671.16
40,088.01

1863975
1,593,018.06

Attachment to Response to AG-2 Question No. 42(c)
Page 3 of 5
Wolfe

 Kentucky Utilities Company
Case No. 2016-00370
10Yr Monthly avg

10Yr Monthly avg

2018
Jan
Feb
Mar
Apr
May
Jun
Jul
Aug
Sep
Oct
Nov
Dec
Total
0.085829392 0.145008982 0.075802634 0.103345187 0.096084097 0.100804414 0.158119084 0.104881833 0.016830949 0.036444172
0.02890031 0.047948946
48.37
81.72
42.72
58.24
54.15
56.81
89.11
59.11
9.49
20.54
16.29
27.02
16,223.52
27,409.68
14,328.26
19,534.37
18,161.87
19,054.11
29,887.76
19,824.82
3,181.40
6,888.70
5,462.75
9,063.34
189,020.58
36,020.65
60,856.98
31,812.65
43,371.63
40,324.31
42,305.32
66,358.99
44,016.53
7,063.57
15,294.79
12,128.80
20,123.08
419,677.30
55.77
94.22
49.25
67.15
62.43
65.50
102.74
68.15
10.94
23.68
18.78
31.15
649.75
5,390.81
9,107.78
4,761.04
6,490.95
6,034.89
6,331.36
9,931.21
6,587.46
1,057.13
2,289.00
1,815.18
3,011.60
62,808.41
5,279.30
8,919.40
4,662.57
6,356.69
5,910.06
6,200.41
9,725.79
6,451.21
1,035.26
2,241.66
1,777.64
2,949.31
61,509.29
9,515.61
16,076.65
8,403.98
11,457.53
10,652.52
11,175.84
17,530.13
11,627.89
1,865.99
4,040.44
3,204.08
5,315.94
110,866.60
264,578.68
447,006.38
233,670.08
318,573.08
296,189.96
310,740.86
487,419.73
323,309.96
51,883.28
112,343.23
89,088.43
147,807.98
3,082,611.66
2,268.66
3,832.91
2,003.63
2,731.65
2,539.72
2,664.49
4,179.44
2,772.26
444.88
963.30
763.90
1,267.40
26,432.25
2,638.98
4,458.57
2,330.69
3,177.54
2,954.28
3,099.42
4,861.66
3,224.79
517.50
1,120.54
888.59
1,474.28
30,746.85
2.04
3.45
1.80
2.46
2.29
2.40
3.76
2.49
0.40
0.87
0.69
1.14
23.78
9,686.62
16,365.57
8,555.01
11,663.44
10,843.96
11,376.69
17,845.17
11,836.86
1,899.52
4,113.05
3,261.66
5,411.47
112,859.04
524.39
885.96
463.13
631.41
587.05
615.89
966.06
640.80
102.83
222.66
176.57
292.95
6,109.71
65.23
110.21
57.61
78.54
73.02
76.61
120.17
79.71
12.79
27.70
21.96
36.44
760.00
352,298.74
595,209.64
311,142.51
424,194.77
394,390.61
413,765.81
649,021.88
430,502.15
69,084.98
149,590.20
118,625.36
196,813.15
4,104,639.80
304.81
514.98
269.20
367.02
341.23
357.99
561.54
372.47
59.77
129.43
102.64
170.28
3,551.36
37,709.90
63,710.97
33,304.55
45,405.62
42,215.39
44,289.31
69,471.01
46,080.76
7,394.83
16,012.07
12,697.61
21,066.79
439,358.80
70,204.47
118,610.63
62,003.05
84,531.58
78,592.34
82,453.34
129,334.09
85,788.48
13,766.94
29,809.65
23,639.12
39,220.02
817,953.71
129.37
218.58
114.26
155.77
144.83
151.95
238.34
158.09
25.37
54.93
43.56
72.27
1,507.33
6,626.58
11,195.62
5,852.45
7,978.91
7,418.31
7,782.75
12,207.80
8,097.55
1,299.46
2,813.72
2,231.29
3,701.97
77,206.40
305,223.83
515,676.46
269,566.98
367,512.96
341,691.30
358,477.54
562,298.20
372,977.53
59,853.70
129,601.64
102,774.39
170,514.56
3,556,169.09
8,636.16
14,590.82
7,627.27
10,398.61
9,667.99
10,142.95
15,909.96
10,553.22
1,693.53
3,667.02
2,907.95
4,824.63
100,620.13
3,026.31
5,112.95
2,672.77
3,643.91
3,387.88
3,554.32
5,575.21
3,698.09
593.45
1,285.01
1,019.01
1,690.66
35,259.56
8,822.73
14,906.02
7,792.04
10,623.24
9,876.85
10,362.06
16,253.65
10,781.20
1,730.12
3,746.23
2,970.77
4,928.85
102,793.76
504.19
851.84
445.29
607.09
564.43
592.16
928.85
616.12
98.87
214.09
169.77
281.67
5,874.38
103.04
223.12
176.94
293.56
6,122.34
525.48
887.79
464.09
632.71
588.26
617.16
968.06
642.12
1,373.97
2,321.32
1,213.46
1,654.36
1,538.13
1,613.69
2,531.19
1,678.96
269.43
583.40
462.64
767.57
16,008.12
429.27
725.25
379.12
516.87
480.56
504.17
790.82
524.56
84.18
182.27
144.54
239.81
5,001.43
1,493.27
2,522.88
1,318.82
1,798.01
1,671.68
1,753.81
2,750.97
1,824.75
292.83
634.06
502.81
834.22
17,398.10
445,010.33
751,846.12
393,023.35
535,826.66
498,179.18
522,653.20
819,819.70
543,793.90
87,265.52
188,956.64
149,843.04
248,606.87
5,184,824.52
1.00
0.057638486 0.104122247 0.083252597 0.085830919 0.110687585 0.096977645
0.20947868 0.092400201 0.060417183 0.035243372 0.024408515 0.039542571
Jan
Feb
Mar
Apr
May
Jun
Jul
Aug
Sep
Oct
Nov
Dec
Total
2017

(0.00)

2506.12
13,717.40

4670.48
15,308.01

3075.68
11,252.58

4157.87
15,376.50

2320.93
15,840.94

12343.76
6,710.35

3075.68
26,812.08

6643.08
13,181.74

5240.05
-

7756.37
-

3645.26
1,817.49

13568.2
-

69003.48
120,017.10

(0.00)

117358.9
147,219.78

103448.71
294,058.74

123905.31
109,764.77

111337.59
207,235.49

117351.14
154,573.85

106300.35
204,440.51

122554.8
364,864.93

114231.24
209,078.72

101382.21
-

111559.5
783.73

113353.4
-

115633.76
32,174.22

1358416.91
1,724,194.75

0.00

2506.12
35,203.78

4670.48
59,040.49

3075.68
30,228.87

4157.87
41,247.75

2320.93
39,894.46

12343.76
31,945.55

3075.68
66,395.33

6643.08
39,437.68

5240.05
2,154.78

7756.37
8,255.70

3645.26
9,052.35

13568.2
7,498.59

69003.48
370,355.32

0.00

123165.95
182,057.88

124167.77
342,197.83

116908.18
152,658.80

110301.59
241,000.06

111142.29
230,549.01

109640.46
248,837.08

101911.01
460,387.19

111866.09
261,111.44

109164.56
-

119886.66
9,714.98

118985.7
-

130046.26
40,468.30

1387186.52
2,168,982.57

Attachment to Response to AG-2 Question No. 42(c)
Page 4 of 5
Wolfe

 Kentucky Utilities Company
Case No. 2016-00370
10Yr Monthly avg

2019
Jan
Feb
Mar
Apr
May
Jun
Jul
Aug
Sep
Oct
Nov
Dec
Total
0.085829392 0.145008982 0.075802634 0.103345187 0.096084097 0.100804414
0.158119084 0.104881833 0.016830949 0.036444172
0.02890031 0.047948946
49.72
84.00
43.91
59.87
55.66
58.40
91.60
60.76
9.75
21.11
16.74
27.78
16,675.97
28,174.10
14,727.85
20,079.15
18,668.38
19,585.50
30,721.28
20,377.71
3,270.12
7,080.81
5,615.10
9,316.10
194,292.07
37,025.21
62,554.19
32,699.85
44,581.20
41,448.90
43,485.15
68,209.64
45,244.08
7,260.56
15,721.34
12,467.06
20,684.29
431,381.45
57.32
96.85
50.63
69.02
64.17
67.32
105.60
70.05
11.24
24.34
19.30
32.02
667.87
5,541.15
9,361.79
4,893.82
6,671.97
6,203.19
6,507.94
10,208.17
6,771.17
1,086.61
2,352.84
1,865.81
3,095.59
64,560.04
5,426.54
9,168.15
4,792.60
6,533.97
6,074.89
6,373.33
9,997.03
6,631.12
1,064.13
2,304.17
1,827.21
3,031.56
63,224.69
9,780.99
16,525.01
8,638.35
11,777.06
10,949.60
11,487.52
18,019.01
11,952.18
1,918.03
4,153.12
3,293.44
5,464.19
113,958.50
271,957.37
459,472.69
240,186.78
327,457.59
304,450.24
319,406.94
501,013.11
332,326.57
53,330.23
115,476.31
91,572.97
151,930.11
3,168,580.91
2,331.93
3,939.81
2,059.51
2,807.83
2,610.55
2,738.80
4,296.00
2,849.58
457.29
990.17
785.20
1,302.74
27,169.40
2,712.58
4,582.91
2,395.69
3,266.16
3,036.67
3,185.86
4,997.25
3,314.72
531.93
1,151.79
913.37
1,515.39
31,604.33
2.10
3.54
1.85
2.53
2.35
2.46
3.87
2.56
0.41
0.89
0.71
1.17
24.45
9,956.77
16,821.98
8,793.60
11,988.71
11,146.38
11,693.97
18,342.84
12,166.97
1,952.50
4,227.76
3,352.62
5,562.39
116,006.50
539.02
910.67
476.05
649.02
603.42
633.06
993.00
658.67
105.70
228.87
181.50
301.12
6,280.10
67.05
113.28
59.22
80.73
75.06
78.75
123.52
81.93
13.15
28.47
22.58
37.46
781.20
362,123.80
611,809.11
319,819.79
436,024.90
405,389.55
425,305.09
667,122.09
442,508.18
71,011.66
153,762.04
121,933.64
202,301.96
4,219,111.80
210.40
380.09
303.91
313.32
404.05
354.01
764.68
337.30
220.55
128.65
89.10
144.35
3,650.40
26,030.22
47,022.84
37,597.86
38,762.26
49,987.82
43,796.25
94,603.05
41,729.02
27,285.11
15,916.32
11,023.17
17,857.89
451,611.83
48,460.43
87,542.36
69,995.88
72,163.65
93,062.27
81,535.43
176,122.38
77,686.87
50,796.66
29,631.40
20,521.83
33,246.02
840,765.17
89.30
4,574.17
210,688.56
5,961.33
2,088.99
6,090.11
348.03
362.72
948.42
296.31
1,030.77
307,179.77

10Yr Monthly avg

161.32
8,263.10
380,602.75
10,768.98
3,773.69
11,001.61
628.71
655.25
1,713.29
535.28
1,862.05
554,911.31

128.99
6,606.89
304,316.98
8,610.51
3,017.32
8,796.51
502.70
523.92
1,369.89
427.99
1,488.83
443,688.16

132.98
6,811.50
313,741.63
8,877.17
3,110.76
9,068.94
518.27
540.14
1,412.31
441.25
1,534.94
457,429.12

171.50
8,784.12
404,601.32
11,448.00
4,011.64
11,695.31
668.36
696.57
1,821.32
569.04
1,979.46
589,900.76

150.25
7,696.10
354,486.76
10,030.04
3,514.75
10,246.71
585.57
610.29
1,595.72
498.55
1,734.28
516,834.72

324.56
16,624.14
765,716.87
21,665.60
7,592.11
22,133.63
1,264.88
1,318.27
3,446.88
1,076.91
3,746.17
1,116,400.12

143.16
7,332.84
337,754.62
9,556.61
3,348.85
9,763.05
557.93
581.48
1,520.41
475.02
1,652.42
492,439.59

93.61
4,794.68
220,845.65
6,248.72
2,189.69
6,383.71
364.81
380.21
994.14
310.60
1,080.46
321,988.62

54.60
2,796.90
128,826.69
3,645.09
1,277.32
3,723.83
212.81
221.79
579.91
181.18
630.27
187,826.78

37.82
1,937.05
89,221.54
2,524.48
884.64
2,579.02
147.38
153.60
401.63
125.48
436.51
130,083.26

61.27
3,138.08
144,541.74
4,089.74
1,433.14
4,178.09
238.77
248.84
650.66
203.29
707.15
210,739.01

1,549.36
79,359.56
3,655,345.12
103,426.27
36,242.89
105,660.52
6,038.21
6,293.09
16,454.57
5,140.92
17,883.31
5,329,421.22
1.00

0.057638486 0.104122247 0.083252597 0.085830919 0.110687585 0.096977645
0.20947868 0.092400201 0.060417183 0.035243372 0.024408515 0.039542571
Jan
Feb
Mar
Apr
May
Jun
Jul
Aug
Sep
Oct
Nov
Dec
Total
2018

(0.00)

3645.53
13,030.44

5810.07
15,623.02

4215.14
10,512.71

5297.41
14,781.74

7389.82
11,278.56

11781.06
7,804.44

4215.14
26,506.14

7893.95
12,483.76

6949.3
-

9203.78
-

4784.76
830.34

10254.96
-

81440.92
112,851.15

(0.00)

110207.7
161,749.67

105174.4
306,928.14

113146.4
127,040.38

119010.31
193,248.08

126371
178,079.24

103642.11
215,764.83

129452.2
371,560.91

114431.4
217,895.17

100700.38
-

113885.77
1,590.54

106772.17
-

123806.64
28,123.47

1366600.48
1,801,980.43

3645.53
22,384.69

5810.07
41,212.77

4215.14
33,382.72

5297.41
33,464.85

7389.82
42,598.00

11781.06
32,015.19

4215.14
90,387.91

7893.95
33,835.07

6949.3
20,335.81

9203.78
6,712.54

4784.76
6,238.41

10254.96
7,602.93

81440.92
370,170.91

130854.08
79,834.48

132631.54
219,139.01

121724.62
182,592.36

109403.94
204,337.69

113172.36
291,428.96

116712.44
237,774.32

107067.26
658,649.61

116456.05
221,298.57

120164.87
100,680.78

120697.37
8,129.32

118053.74
-

133956.98
10,584.76

1440895.25
2,214,449.87

-

(0.00)

Attachment to Response to AG-2 Question No. 42(c)
Page 5 of 5
Wolfe

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 43
Responding Witness: Daniel K. Arbough
Q-43. Refer to the response to AG-1-231. What were the comparable budgeted/forecast
amounts for years 2014, 2015 and 2015?

A-43. The amount of affiliate operating expenses was not compiled for the budgets for
calendar years 2014, 2015, or 2016.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 44
Responding Witness: Valerie L. Scott / Daniel K. Arbough
Q-44.

Refer to the response to AG-1-233(a).
a. Explain the basis for the exclusion of items from the current KU and LGE
rate cases on the attachment.
b. What amount of ash pond and landfill closure costs has the Company reflected
for the Forecast Test Year ended 6/30/2018 by account?

A-44.
a. We assume the question is referring to the footnote on the attachment to AG
1-233(a) which states “Excluded from Case No. 2016-00026 (KU) and 201600027 (LGE)”. Case No. 2016-00026 was an application by KU for
certificates of public convenience and necessity and approval of its 2016
compliance plan for recovery by environmental surcharge rather than a rate
case.
b. Account 107001
Account 108899

$1,466,018
$25,901,700

Note these amounts are part of a previously approved ECR plan and have
been removed from this case.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 45
Responding Witness: Lonnie E. Bellar / John K. Wolfe
Q-45.

Refer to the response to AG-1-236. Identify the comparable amounts of
vegetation management costs for transmission and distribution for the Forecast
Test Year ended 6/30/2018 by account.

A-45.

Forecast Test Year Ended 6/30/2018:
Distribution Account 593 $14,828,868
Transmission Account 571 $9,992,809

 Response to AG-2 Question No. 46
Page 1 of 2
Arbough/Sinclair
KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 46
Responding Witness: Daniel K. Arbough / David S. Sinclair
Q-46.

Refer to the response to AG-1-240. Has a full year's worth of revenue for each of
the customers listed in the response been included in the Forecast Test Year ended
6/30/2018?
a. If not, explain fully why not, and show the amount of revenue and sales for
each of the customers listed in the response that was reflected in the Forecast
Test Year ended 6/30/2018.
b. If so, show the annualized amount of revenue and sales for each of the
customers listed in the response that was reflected in the Forecast Test Year
ended 6/30/2018.

A-46.
a. See the response to part b.
b. KU does not individually forecast all customers as described in Mr. Sinclair’s
direct testimony as well as in the Annual Electric Sales and Demand Forecast
Process attached at Tab 16 of the Companies’ Applications. Seven customers
listed in the response to AG-1-240 are individually forecasted and a full year’s
worth of revenue is included in the Forecast Test Year ended 6/30/18 as
shown below.

Rate Case Customer
Designation
Customer 44-47
Customer 53
Customer 56
Customer 64

Forecast Test Year
Ending 6/30/18 Sales
(kWh)
97,124,112
74,578,364
126,854,337

Forecast Test Year
Ending 6/30/18
Revenue
$ 5,378,815
$ 3,899,014
$
$ 7,777,602

Customer 56 is currently forecasted to be closed completely by 6/30/17. The
list of customers in the response to AG-1-240 was developed based on a

 Response to AG-2 Question No. 46
Page 2 of 2
Arbough/Sinclair
move-in date filter. A change in this date can be caused by a number of
circumstances such as a change in ownership, bankruptcy, consolidation of
service, or a new metering point. Less than 10% of the volumes and revenues
included in the original response are a result of new customers or expanding
service to an existing customer.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 47
Responding Witness: Daniel K. Arbough / David S. Sinclair
Q-47.

Refer to the response to AG-1-241. Has a full year's worth of revenue for each of
the customers listed in the response who are expanding operations been included
in the Forecast Test Year ended 6/30/2018?
a. If not, explain fully why not, and show the amount of revenue and sales for
each of the customers listed in the response that was reflected in the Forecast
Test Year ended 6/30/2018.
b. If so, show the annualized amount of revenue and sales for each of the
customers listed in the response that was reflected in the Forecast Test Year
ended 6/30/2018.

A-47.
a. See the response to part b.
b. KU does not individually forecast all customers as described in Mr. Sinclair’s
direct testimony as well as in the Annual Electric Sales and Demand Forecast
Process attached at Tab 16 of the Companies’ Applications. Three of the
customers listed in the response to AG-1-241 are individually forecasted and
a full year’s worth of revenue is included in the Forecast Test Year ended
6/30/18 as shown below.

Rate Case Customer
Designation
Customer 4
Customer 9
Customer 14

Forecast Test Year
Ending 6/30/18 Sales
(kWh)
97,124,112
532,583,691
204,423,641

Forecast Test Year
Ending 6/30/18
Revenue
$ 5,378,815
$ 31,245,942
$ 10,840,158

The information in the response to AG-1-241 was provided directly by
customers; the size, timing, and likelihood of the expansion is subject to
frequent change.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 48
Responding Witness: Daniel K. Arbough / David S. Sinclair
Q-48.

Refer to the response to AG-1-242. Have all of the estimated reduced load and
estimated reduced revenue amounts listed in the response been reflected by the
Company in the Forecast Test Year ended 6/30/2018? If not, which amounts were
not fully reflected and why?

A-48.

KU does not individually forecast all customers as described in Mr. Sinclair’s
direct testimony as well as in the Annual Electric Sales and Demand Forecast
Process attached at Tab 16 of the Companies’ Applications. Two of the
customers listed in the response to AG-1-242 are individually forecasted. The
impact of reduced revenue from Customer 6 is fully reflected in the test year and
no reduction is included for Customer 1 because this information was not
available until December 2016.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 49
Responding Witness: John P. Malloy
Q-49.

Refer to the responses to AG-1-244 and 245.
a. Has the Company projected any reduction in postage expense for the Forecast
Test Year ended 6/30/2018 related to increasing use of electronic
transmission of bills? If not, explain fully why not. If so, identify the amount
and show how it was derived.
b. Refer to the volume of customer bills, notices and letters in response to AG1- 245(c). How many of those were (1) mailed and (2) electronically
transmitted?

A-49.
a. No. The forecast test year assumes that the increase in electronic bills is offset
by customer growth.
b. The customer bills, notices and letters listed in the response to AG-1- 245(c)
were all mailed.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 50
Responding Witness: William S. Seelye
Q-50.

With regard to the Company’s class cost of service study (“CCOSS”) models
provided in response to PSC 1-53, tab “Functional Assignment, row 481 (Total
Distribution Operation and Maintenance Labor Expenses): confirm or deny that
there is a programming error in that Total System amounts are calculated as the
sum of Distribution Operations Labor plus Distribution Maintenance Labor,
whereas the functional assignment utilizes a lookup table based on Total
Distribution Plant (“PDIST”).
a. If the Company confirms, please provide a summary of class rates of return
under current and proposed rates with this correction. If the Company denies,
please explain why this apparent inconsistency is appropriate considering the
programming functionalization of distribution O&M expenses.

A-50.

Confirmed. The individual classifications of costs should be the sum of
Distribution Operations Labor plus Distribution Maintenance Labor similar to the
Total System amounts referenced. Below is a summary of the class rates of
return, using the Base-Intermediate-Peak (“BIP”) methodology, under both
current and proposed rates with this correction:
Rate of Return on Rate Base
Rate Class
Current Rates Proposed Rates
Residential Service
4.15%
5.63%
General Service
9.02%
10.87%
All Electric Schools
5.25%
7.05%
Power Service-Secondary
9.59%
11.48%
Power Service-Primary
11.64%
13.58%
Time-of-Day Secondary Service
6.43%
8.31%
Time-of-Day Primary Service
4.46%
6.55%
Retail Transmission Service
4.52%
6.73%
Fluctuating Load Service
1.50%
3.44%
Lighting Energy Service
9.83%
9.82%
Traffic Energy Service
8.84%
10.48%
Lighting Service & Restricted Lighting Service
8.48%
9.65%
Total All Classes
5.56%
7.29%

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 51
Responding Witness: John P. Malloy
Q-51.

With respect to Rate Schedule TE (Traffic Energy), provide a separation of the
current number of traffic signals that are metered and unmetered.

A-51.

As of January 2017, there are 494 contract metered accounts and 272 contract
unmetered accounts in the TE rate schedule. Traffic Energy (TE) rate schedule
consists of traffic control devices including signals, cameras, or other traffic lights
and electronic communication devices; therefore, the contract accounts are not
limited to traffic signals.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 52
Responding Witness: John P. Malloy
Q-52.

With respect to Rate Schedule TE (Traffic Energy), provide the current number
of separate accounts; i.e., number of bills rendered monthly.

A-52.

For the month of January 2017, there were 766 contract accounts with respect to
Rate Schedule TE with monthly rendered bills. See also the response to
Question No. 51.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 53
Responding Witness: John P. Malloy
Q-53.

With respect to Rate Schedule LE (Lighting Energy), provide the current number
of separate accounts; i.e., number of bills rendered monthly.

A-53.

For the month of January 2017, there were 5 contract accounts with respect to
Rate Schedule LE.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 54
Responding Witness: John P. Malloy
Q-54.

With respect to Rate Schedules ST and POL (Outdoor Lighting), provide the
current number of separate accounts; i.e., number of bills rendered monthly.

A-54.

For the month of January 2017:
•

The Company no longer has ST or POL rate schedules. These rate
schedules are included in RLS and LS rate schedules.

•

6,691 contract accounts with respect to Rate Schedule RLS.

•

56,606 contract accounts with respect to Rate Schedule LS.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 55
Responding Witness: John P. Malloy
Q-55.

With respect to Rate Schedules ST and POL (Outdoor Lighting), indicate if any
lights are metered. If yes, provide the current number of separately metered lights.

A-55.

The Company no longer has ST or POL rate schedules. These rate schedules are
included in RLS and LS rate schedules. Currently, there are not any RLS or LS
rate schedules that are metered.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 56
Responding Witness: William S. Seelye
Q-56.

With regard to the Company’s CCOSS, confirm or deny that Rate Schedules ST
and POL (Outdoor Lighting) are allocated Meter Reading expenses.

A-56.

Class ST (or Rate LS) and Class POL (or Rate RLS) are not allocated meter
reading expenses.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 57
Responding Witness: John P. Malloy / John K. Wolfe
Q-57.

With regard to customers whose transformer (high side) is served from primary
or secondary voltage lines, provide the current (actual or estimated) number of
customers whose transformers are served at primary and secondary voltage
separately for each of the following Rate Schedules:
a. Residential (RS);
b. General Service (GS); and,
c. All Electric Schools (AES).

A-57.
a. Data responsive to this question is not readily available. There are no known
RS services where the Company provides a secondary to secondary voltage
transformation before the service point. Therefore all Company RS
customers are expected to be served by transformers that perform a primary
to secondary transformation.
b. Data responsive to this question is not readily available. There are no known
GS services where the Company provides a secondary to secondary voltage
transformation before the service point. Therefore all Company GS
customers are expected to be served by transformers that perform a primary
to secondary transformation.
c. Data responsive to this question is not readily available. There are no known
AES secondary customers where the Company provides a secondary to
secondary voltage transformation before the service point. Therefore all
Company AES secondary customers are expected to be served by
transformers that perform a primary to secondary transformation.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 58
Responding Witness: William S. Seelye
Q-58.

With regard to the Company’s response to AG 1-277 concerning hourly Loss of
Load Probabilities (“LOLP”), provide all calculations and components of system
LOLP including the “direct numerical convolution” for each station’s capacity
and availability resulting in a system LOLP of 0.1260% at 1500 hours on August
9, 2017.

A-58.

The hourly LOLPs were produced by PROSYM, which is the software provided
by ABB that the Companies also use to develop the generation forecast. The
attachment to the response to AG 1-276 documents the LOLP calculations
performed in PROSYM. However, the LOLP calculations are performed within
the software. The Companies do not have access to the underlying proprietary
code that performs the LOLP calculations or the calculations’ intermediate
components.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 59
Responding Witness: David S. Sinclair
Q-59.

With regard to the Company’s response to KIUC 1-52(a), is the column entitled
“Company” meant to refer to individual CSR customers?

A-59.

Yes.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 60
Responding Witness: David S. Sinclair
Q-60.

With regard to the Company’s response to KIUC 1-52(a), explain why there are
no customers (Companies) referred to as 1, 2, or 3.

A-60.

KIUC 1-52(a) was created from a list of customers including both LG&E and
KU. The customers referred to as 1, 2, and 3 are included in the Attachment to
Response to KIUC 1-51 in Case No. 2016-00371.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 61
Responding Witness: David S. Sinclair
Q-61.

With regard to the Company’s response to KIUC 1-52(a) and 1-53(a), provide the
following:
a. an explanation of whether the customers provided in response to KIUC 152(a) have been curtailed at any time during the last 60 months; if yes, provide
a list of all curtailments for each customer; and,
b. an explanation why Customer 3 in KIUC 1-53(a) is not included in the list
provided in response to KIUC 1-52(a).

A-61.
a. The table in the Company’s response to KIUC 1-53(a) is complete and covers
the last five years.
b. The numbers associated with customers in responses to KIUC 1-53(a) and
KIUC 1-52(a) are not intended to represent any information other than
anonymizing individual customers. As such, the numbers do not necessarily
represent the same customer in each response.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 62
Responding Witness: David S. Sinclair
Q-62.

With regard to the Company’s response to KIUC 1-53(a), provide a detailed
explanation of what is meant by the column entitled “Load Not Compliant
(kVA).”

A-62.

The entries in the “Load Not Compliant (kVA)” column represent the difference
between the customer’s maximum demand during the identified curtailment
period and the firm demand that the customer contractually committed not to
exceed during any curtailment period.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 63
Responding Witness: David S. Sinclair
Q-63.

With regard to the Company’s response to KIUC 1-53(a), provide a detailed
explanation as to why only Customer 3 and Customer 4 were curtailed on January
30, 2014. In this response, explain why other CSR customers were not curtailed
during this time period.

A-63.

Curtailing customers under the CSR tariff is a manual process. As such, it is part
of the dynamic nature of system dispatch and the real-time demands on system
dispatch personnel. On January 30, 2014, the Company curtailed the relatively
larger loads of Customers 3 and 4 and did not continue pursuing curtailment of
other smaller loads based on system needs that were present at that time. During
January 2014, there were no other KU customers registered for CSR10. The
CSR10 rider in effect at the time required a ten (10) minute advance notification
prior to curtailment. There were only two other customers registered under
CSR30, one of which was registered for CSR30 just prior to the January 30.
CSR30 required a 30 minute advance notification.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 64
Responding Witness: David S. Sinclair
Q-64.

With regard to the Company’s response to KIUC 1-53(a), provide a detailed
explanation as to why only Customer 3, Customer 4, and Customer 5 were
curtailed on January 7, 2014. In this response, explain why other CSR customers
were not curtailed during this time period.

A-64.

Customer 3, Customer 4, and Customer 5 represented all three customers under
the CSR10 and CSR30 tariffs on January 7, 2014. Also, see the response to
Question No. 63.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 65
Responding Witness: David S. Sinclair
Q-65.

With regard to the Company’s response to KIUC 1-53(a), provide a detailed
explanation as to why only Customer 3 was curtailed on January 6, 2014. In this
response, explain why other CSR customers were not curtailed during this time
period.

A-65.

The Company’s response to Question No. 63 also applies to the situation
encountered on January 6, 2014.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 66
Responding Witness: David S. Sinclair
Q-66.

Provide system peak load at generation (KU and LG&E) and total system
generation output (KU and LG&E) for each of the following hours:
a. January 30, 2014, hour ending 0800;
b. January 7, 2014, hour ending 1000;
c. January 7, 2014, hour ending 0900;
d. January 7, 2014, hour ending 0800; and,
e. January 6, 2014, hour ending 1900.

A-66.
All volumes in MW:
Total
EST
KU
LG&E System
Total
(Hour Ending)
Load
Load
Load Generation*
2014-01-30 08:00 4,656
1,805
6,461
6,700
2014-01-07 10:00 4,939
1,938
6,877
6,902
2014-01-07 09:00 5,068
1,948
7,016
7,030
2014-01-07 08:00 5,045
1,936
6,981
7,018
2014-01-06 19:00 4,985
2,096
7,081
7,589
*Note: Total Generation includes OVEC and market purchases.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 67
Responding Witness: John P. Malloy
Q-67.

With respect to write-offs or uncollectible expenses, provide a list and amount of
any write-offs during the last five years associated with customers served under
the following Rate Schedules:
a. Power Service (PS);
b. Time of Day (TOD);
c. Retail Transmission Service (RTS); and,
d. Fluctuating Load Service (FLS).

A-67.
a-d. The Company does not have a business reason to maintain the requested
information and therefore cannot provide the requested response.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 68
Responding Witness: Valerie L. Scott
Q-68.

Provide details of booked uncollectible expense for each of the last three years by
rate class or customer group as available; i.e., in the finest level of detail available
other than on a total Company basis.

A-68.

Uncollectible expense is not recorded on a rate class or customer group level as
it is booked only on a total Company basis.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 69
Responding Witness: William S. Seelye
Q-69.

With regard to the Company’s CCOSS, explain why Rate PS-Secondary and Rate
TOD-Secondary are not allocated any secondary lines (overhead or underground)
costs.

A-69.

For customers taking service under Power Service-Secondary (PSS), the twelvemonth average demand requirements range from 50kW to 250kW, and for
customers taking service under Time-of-Day-Secondary (TODS), the twelvemonth average demand requirements range from 250kW to 5,000kW.
Due to the large demand requirements for these customers, the Company does
not normally install secondary conductor between the transformer and service
drop due to voltage drop concerns associated with long secondary conductor
spans serving customers with large loads. For these customers, the Company
typically installs a distribution pole very close to the customer’s equipment which
will support the transformers and service wire leading directly into the customer’s
meter with no additional secondary conductor.
Since secondary conductor and associated distribution equipment are normally
not installed for these customers, it is not appropriate for these customers to be
allocated secondary distribution costs in the Company’s class cost of service
studies.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 70
Responding Witness: William S. Seelye
Q-70.

With regard to the Company excluding an allocation of secondary lines costs to
Rate PS-Secondary and Rate TOD-Secondary in this case, explain what facts and
circumstances have changed since Case No. 2012-00221, wherein the Company
did allocate secondary lines costs to these classes.

A-70.

Prior to the Company’s 2014 Rate Application, it was determined that changes to
the allocation of Secondary distribution were warranted based on the information
provided by the Company’s Distribution Engineering department as explained in
the response to Question No. 69. These changes were incorporated in the cost of
service study filed by KU in Case No. 2014-00371.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 71
Responding Witness: William S. Seelye
Q-71.

Explain the time period utilized to estimate class contributions to peak demands
within Mr. Seeyle’s CCOSS; e.g., Residential Summer CP Demand equals
1,347,051 and Residential NCP Demand equals 2,135,688.

A-71.

The summer Coincident Peak (CP) demands used in the CCOSS are each class’s
contribution to the highest hourly system peak during the summer months (May
– Sept) adjusted for losses during the forecasted test period. The Non-Coincident
Peak (NCP) demands are each class’s highest hourly demand adjusted for losses
during any hour of the forecasted test period.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 72
Responding Witness: William S. Seelye
Q-72. Explain and reconcile differences in class contributions to coincident peak and noncoincident peak demands contained in Mr. Seeyle’s CCOSS (tab: Allocation
Proforma) with those provided in response to PSC 2-97. In this response, also
indicate if the amounts provided in PSC 2-97 are Kentucky only.
A-72. The response to PSC 2-97 shows each class’s contribution to the highest hourly
peak load during the summer months (Coincident Peak) multiplied by the Loss of
Load Probability (LOLP) during that hour. The allocators used to allocate
Production Demand costs in the LOLP version of the Cost of Service Study are the
summation of each class’s hourly load multiplied by the LOLP for each hour for
the entire twelve month test period. The demand values provided in PSC 2-97 are
only for Kentucky jurisdictional customers and do not include any wholesale or
Virginia customer demands.
The non-coincident peak demands are the same in both versions of the cost of
service studies filed and are simply the highest class hourly demand forecasted for
the test period.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 73
Responding Witness: William S. Seelye
Q-73.

Explain and reconcile differences in class contributions to coincident peak and
non-coincident peak demands contained in Mr. Seeyle’s CCOSS (tab: Allocation
Proforma) with those provided in response to OAG 1-274(d), Attachment 3. In
this response, also indicate if the amounts provided in OAG 1-274(d) are
Kentucky only.

A-73.

The class coincident and non-coincident peaks in Attachment 3 provided in
response to AG 1-274(d) are for July 1, 2015 through June 30, 2016. The
information used to develop the demand allocations for the class cost of service
studies are contained in Attachment 4 in the response to the same question under
the tab “KU 8760s Test Year EMS Shape (2”.
The amounts referenced in AG 1-274(d) are for Kentucky customers only.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 74
Responding Witness: William S. Seelye
Q-74.

With regard to the attachment to PSC 2-97, explain and separate (as appropriate)
what rate schedules (consistent with the Company’s CCOSS) are included in the
following classes or categories. In other words, for the following three categories,
define and separate consistent with the classes within the Company’s CCOSS:
a. Industrial Service Trans;
b. Muni Primary; and,
c. Muni Secondary.
In this response, also indicate if the amounts provided in PSC 2-97 are Kentucky
only. Provide hourly loads by class consistent with the CCOSS. Provide in
electronic (Excel) format.

A-74.
a. “Industrial Service Trans” corresponds to Fluctuating Load Service (“FLS”)
in the Company’s class cost of service studies.
b. “Muni Primary” represents FERC-regulated wholesale customers served at
primary voltage, which are not a part of this proceeding and therefore are not
in the Company’s class cost of service studies.
c. “Muni Secondary” should have been labeled “Muni Transmission”
throughout the file. Muni Secondary therefore represents FERC-regulated
wholesale customers served at transmission voltage, which are not a part of
this proceeding and therefore are not in the Company’s class cost of service
studies.
The amounts provided in PSC 2-97 are for the Kentucky jurisdiction only. The
hourly loads used to develop demand allocators were provided in the attachment
referenced for PSC 2-97.

 Response to AG-2 Question No. 75
Page 1 of 2
Seelye
KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 75
Responding Witness: William S. Seelye
Q-75.

With regard to the attachment to OAG 1-274, explain and separate (as
appropriate) what rate schedules (consistent with the Company’s CCOSS) are
included in the following classes or categories. In other words, for the following
four categories, define and separate consistent with the classes within the
Company’s CCOSS:
a. Industrial Service Trans;
b. Muni Primary;
c. Muni Secondary; and,
d. Comp 1.
In this response, also indicate if the amounts provided in OAG 1-274(d) are
Kentucky only. Provide hourly loads by class consistent with the CCOSS.
Provide in electronic (Excel) format.

A-75.
a. “Industrial Service Trans” corresponds to Fluctuating Load Service (“FLS”)
in the Company’s class cost of service studies.
b. “Muni Primary” represents FERC-regulated wholesale customers served at
primary voltage, which are not a part of this proceeding and therefore are not
in the Company’s class cost of service studies.
c. “Muni Secondary” should have been labeled “Muni Transmission”
throughout the file. Muni Secondary therefore represents FERC-regulated
wholesale customers served at transmission voltage, which are not a part of
this proceeding and therefore are not in the Company’s class cost of service
studies.
d. “Comp 1” is a wholesale customer, whose cost of service is not a part of this
proceeding and therefore not in the Company’s class cost of service studies.

 Response to AG-2 Question No. 75
Page 2 of 2
Seelye
Comp 1 was identified as such to maintain the confidentiality of the
customer’s load information.
The hourly loads used to develop demand allocators were provided in the
attachment referenced for PSC 2-97.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 76
Responding Witness: John P. Malloy / David S. Sinclair
Q-76.

Provide:
a. The cost per avoided MW used for the cost-benefit tests in the Companies'
most recent DSM application (2014-00003).
b. The cost per (avoided) MW used in the Companies' most recent Integrated
Resource Plan (2014-00131).

A-76.
a. The cost per avoided MW used in DSM application 2014-00003 was
$99.92/kW-year.
b. The cost per avoided MW used in the Companies’ 2014 Integrated Resource
Plan was $99.92/kW-year.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 77
Responding Witness: John P. Malloy
Q-77.

Reference the Malloy testimony at page 21, line 17, in which Mr. Malloy
indicates that the AMS experience of the Companies’ affiliate, PPL Electric
Utilities, was used in the development of the Companies’ AMS Business Case.
The Companies’ AMS Business Case indicates a net present value for the
Recovery of Non-technical Losses over 20 years at $489 million (page 31). It is
the OAG’s understanding that PPL’s Pennsylvania deployment of AMS has just
begun. Provide the following data from any AMS business case PPL Electric
Utilities developed for its Pennsylvania AMS deployment:
a. Present value of reductions in non-technical losses
b. Business processes and technologies to be employed to reduce non-technical
losses
c. Utility revenues and customer counts for bundled and delivery-only service

A-77.

KU is unaware of a business case prepared by PPL for AMS deployment. PPL
Electric Utilities was required to install smart meters by legislative action.

 Response to AG-2 Question No. 78
Page 1 of 2
Malloy
KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 78
Responding Witness: John P. Malloy
Q-78.

Reference the AMS Business Case, Exhibit JPM-1, page 34, “Reduced Staffing
for Ad-Hoc Field Services” and the Companies’ response to AG-1-320 [Case No.
2016- 00370]. Complete the table below, where “Total Count, 2016” is the
number of each operation performed in 2016; “Count of Unique Customers,
2016” is the number of unique customers for which each operation was performed
(i.e., a customer disconnected for non-payment 6 times in 2016 equals 1); and
“Cost, 2016” is the cost of all such operations in 2016.
Total Count
2016

Count of Unique
Customers, 2016

Cost, 2016

Off-Cycle Meter Reads
Meter Re-reads
Move-in Connections
Bill Payment Reconnections
Disconnections for Non-Payment
Disconnections for all other reasons
TOTALS

A-78.

See the tables below.
KU Kentucky Only

Total Count
Count of Unique
2016
Customers, 2016
Off-Cycle Meter Reads
132,756
98,056
Meter Re-reads
*
*
Move-in Connections
489
432
Bill Payment Reconnections
74,279
45,272
Disconnections for Non-Payment
87,309
53,676
Disconnections for all other reasons
1,290
851
TOTALS
296,123
198,287
*The Company characterizes all Meter Re-reads as Off-Cycle Meter reads.

Cost, 2016
$2,196,209
*
$8,090
$1,228,813
$1,444,371
$21,341
$4,898,824

 Response to AG-2 Question No. 78
Page 2 of 2
Malloy

KU Virginia Only

Total Count
Count of Unique
2016
Customers, 2016
Off-Cycle Meter Reads
5,804
4,607
Meter Re-reads
*
*
Move-in Connections
42
38
Bill Payment Reconnections
2,903
1,944
Disconnections for Non-Payment
3,679
2,511
Disconnections for all other reasons
66
42
TOTALS
12,494
9,142
*The Company characterizes all Meter Re-reads as Off-Cycle Meter reads.

Cost, 2016
$96,017
*
$695
$48,025
$60,862
$1,092
$206,691

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 79
Responding Witness: John P. Malloy
Q-79.

Reference the AMS Business Case, Exhibit JPM-1, page 38. The AMS CostBenefit Summary 2016-2039 indicates that the net present value of meter
retirement is only $3.8 million, while the nominal value of meter retirement is
$39.7 million.
a. Explain why the net present value of meter retirement is so much less than
the nominal value.
b. Provide all assumptions and calculations used to determine a net present value
of $3.8 million from a nominal value of $39.7 million. Include calculations
by year over the 20-year benefit period utilized in the AMS business case in
an executable MS Excel file with all cells and equations intact.

A-79.
a. The net present value calculation, as seen in the attachment to part b, includes
a reduction in capital equal to the net book value of the retired meters. The
Company is seeking Regulatory Asset treatment of this remaining value to be
amortized over five years. Because the remaining book life of the retired
meters is substantially longer than the 5-year amortization, the present value
of the meter retirement is proportionally reduced from the nominal value.
b. See attachment being provided in Excel format. Note that since the
Regulatory Asset amortization will be concluded in 2025, the attached
calculation only extends 10 years.

 The attachment is being
provided in a separate
file in Excel format.

KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 80
Responding Witness: John P. Malloy
Q-80.

Reference the AMS Business Case, Exhibit JPM-1, page 40. The Meter Capital
cost indicated in the table entitled “Project Costs 2016-2021” is $167 million, or
approximately $176.53 per customer assuming 945,000 customers. Provide:
a. The number of smart meters to be installed for the $167 million capital cost
estimate;
b. The portion of the capital cost estimate associated with the optional remote
service disconnect-reconnect switch offered by Landis + Gyr; and
c. The number of smart meters to be equipped with the optional remote service
disconnect-reconnect switch offered by Landis + Gyr.

A-80.
a. Included in the meter capital estimate of $167 million is the installation of
978,436 AMS electric meters and 321,637 AMS gas indices.
b. Remote disconnect-reconnect functionality increases the cost of the Landis +
Gyr AMS electric meter by approximately $20/meter, which equates to
approximately $19.6 million for the installed electric meters. Due to the
requirement to inspect customer gas appliances when a gas reconnection is
performed, remote reconnect-disconnect functionality of AMS gas indices is
not practical and is not included in the AMS Business Case.
c. The Companies plan to install 933,174 AMS electric meters with remote
service disconnect-reconnect switches. Not all AMS electric meters can be
equipped with the remote disconnect-reconnect service switch because the
service switch is designed and rated at maximum current adequate only for
single-phase, residential class and small business electric services.

 Response to AG-2 Question No. 81
Page 1 of 2
Malloy
KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 81
Responding Witness: John P. Malloy
Q-81.

Reference the AMS Business Case, Exhibit JPM-1, page 158. The Companies
provide the following estimates used to calculate non-technical loss reduction
benefits:
•
2% of revenues are lost due to non-technical losses
•
AMS will detect 60% of such losses
•
60% of losses detected will be recovered
a. Provide any studies or research (other than the EPRI report the Company
cited) which support any of these three estimates.
b. Explain how the Companies used existing experience to determine each of
these three estimates. For any of the three estimates which were not developed
through the benefit of existing experience, describe how the Companies
developed each.
c. Provide, for 2014, 2015, and 2016:
i. The dollar value of non-technical line losses identified and
quantified; and
ii. Of non-technical line losses identified and quantified, the dollars
actually recovered to date from customers and/or thieves.

A-81.
a. KU relied solely on the 2008 EPRI report.
b. KU's experience with finding non-technical losses is limited to theft and
metering issues (i.e. meter malfunction, non-read, misread). The EPRI report
shows that with the additional data provided from AMS additional losses will
be identified. The Company discounted the 2% from the study to be
conservative and reflect the lack of company experience in this area. 60%
was considered a good estimate.
See the response to Question No. 82
for further explanation.

 Response to AG-2 Question No. 81
Page 2 of 2
Malloy
c.i. See the table below. The Tampering Fees Billed represents the dollar value
of non-technical line losses identified and quantified.
c.ii. The table below reflects the nominal dollars recovered from tampering fees
for 2014 through 2016.
LG&E/KU Combined
Tampering Fees Billed
Tampering Fees Collected
Recovery Percentage

2014

2015

2016

$380,620
$234,630
62%

$418,578
$246,639
59%

$386,947
$215,411
56%

Total
2014-2016
$1,186,145
$696,680
59%

 Response to AG-2 Question No. 82
Page 1 of 2
Malloy
KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 82
Responding Witness: John P. Malloy
Q-82. Reference the Companies’ response to KIUC 1-16 (c) [Case No. 2016-00370].
Explain how the report provided, “2010 Analysis of System Losses”, supports the
Companies’ estimate that 2% of its revenues are lost through non-technical means.
Cite any specific text, tables, charts, appendices, or other components of the report
applicable to the Companies’ response.

A-82. The 2008 EPRI report and the 2010 Analysis of System Losses were performed
independent of each other and for different purposes.
The objective of the EPRI report, provided in response to KIUC 1-16 (a) [Case No.
2016-00370], is found on page 5, which states, "Revenue security involves securing
revenue that is due distribution utilities from delivery of electricity to end-users. It
includes both reducing losses and collecting revenue associated with the electricity
delivered. Non-technical distribution losses occur at the point of delivery and
measurement. Minimizing non-technical losses increases the amount of electricity
that is delivered, measured, and billed. This is the challenge to revenue security."
The purpose of the 2010 Analysis of System Losses, provided in response to KIUC
1-16 (c) [Case No. 2016-00370] is found on page 1 in the executive summary which
states, "This report presents KU 2010 Analysis of System Losses for the power
systems as performed by Management Applications Consulting, Inc. (MAC). The
study developed separate demand (kW) and energy (kWh) loss factors for each
voltage level of service in the power system for KU. The cumulative loss factor
results by voltage level, as presented herein, can be used to adjust metered kW and
kWh sales data for losses in performing cost of service studies, determining voltage
discounts, and other analysis which may require a loss adjustment.” It does not
attempt to quantify non-technical losses.
The Company used 2% from the EPRI study. The 2% was then multiplied by 60%
to account for the portion of non-technical losses which could reasonably be
expected to be found through the new data and analytics. Additionally, another
60% was used to represent that portion of found non-technical losses which could
be recovered (turned into actual revenue). See the response to Question No. 81.

 Response to AG-2 Question No. 82
Page 2 of 2
Malloy
Thus, 2% x 60% x 60% = 0.72%
The 0.72% is a reasonable level of non-technical loss that can be found and
recovered through the improved technology of AMS, the data AMS provides, and
the analytics utilizing the data.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 83
Responding Witness: John P. Malloy
Q-83.

Reference the Companies’ response to ACM 1-33 [Case No. 2016-00371]. The
2009 E-On AMI benefit-cost analysis provided as a response to that question,
page 14, indicates that the present value of the combined revenue protection
added to system loss benefits for all three Companies at $28 million. This is a
vast difference from the Companies’ latest AMS benefit-cost analysis, which
estimates the present value of reductions in non-technical losses at $489 million.
Explain the difference between the Companies’ current estimate and the 2009 EOn estimate.

A-83.

The Companies’ estimated benefit of $489 million due to reductions in nontechnical losses is a nominal amount, which equates to a present value of $195
million, which would be more comparable to the $28 million referenced in the
question. $28 million was the best estimate at the time, and was calculated
assuming that total system losses related to distribution only could be reduced by
2%.
The $195 million that the Company currently estimates the present value of
reductions in non-technical losses is based on the 2008 EPRI Report and is further
explained in Company’s response to Question No. 82.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 84
Responding Witness: John P. Malloy
Q-84.

Reference the Companies’ response to PSC 2-29 [Case No. 2016-00370]. Upon
finding a meter base which is sufficiently dysfunctional to prevent the installation
of an AMI meter, the response describes how the affected customer can: 1) allow
the Companies to proceed with meter base repairs at no cost; or 2) repair the meter
base with a contractor of the customer’s own choosing. The Malloy testimony,
pp. 26-27, indicates that customers will not have the opportunity to Opt-Out of
AMI meter installation. With no Opt-Out available, explain what the Companies
propose to do if a customer refuses to repair, or to allow the Companies to repair,
a dysfunctional meter base.

A-84.

See the response to PSC 3-11.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 85
Responding Witness: John P. Malloy
Q-85.

A-85.

Reference the Companies’ response to OAG 1-301 [Case No. 2016-00370]. The
Companies report the following quantities of single-phase electronic meters were
installed in 1999. Report how many of the single-phase electronic meters installed
in 1999 are still in operation by completing the table below.
Meter

Quantity Installed 1999

GE I210
Itron C1S
Landis + Gyr ALF
Landis + Gyr AX
TOTALS

81
1035
283
5
1,404

Quantity Installed 1999 Still In
Operation 12-31-16

The Companies’ response to AG 1-301 parts a, b, and c listed meters currently
installed and in service in Wilmore regardless of the year of initial installation.
AG 1-301, part d, question asked, "Of the meters originally installed in 1999,
provide a count of those still in operation by model." There are 2,615 Sangamo
Model J5S mechanical meters that were installed in 1999 that are still currently
installed and active. These Sangamo Model J5S mechanical meters have a
communication card in the meter that provides power line communication (PLC)
to operate on the TS1 system. There were no single-phase electronic meters
installed in 1999 in the Wilmore area as part of the TS1 system.
Nonetheless, see the table below regarding the meters at issue in this request,
which shows the years the Companies acquired the meters (usually the same years
they were first placed in service):
Meter Models

2001

2002

2003

GE I210

2007

2009

2010

2011

2012

2013

2014

81

Itron C1S

83

88

81
89

229

109

221

216

Landis + Gyr ALF

1035
283

Landis + Gyr AX

5

Total

5

Total

283
5

83

88

81

89

229

109

221

216

283

1404

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 86
Responding Witness: John P. Malloy
Q-86.

Reference the Company’s response to OAG 1-302.f [Case No. 2016-00370]. The
Company reports the following meters from the 2007 pilot are still in operation.
Provide the quantities originally installed by completing the table below.
Meter
Landis + Gyr ALF
Landis + Gyr AX
TOALS

A-86.

Quantity Installed in 2007

Quantity Still in Operation
331
45
376

The meters associated with the pilot were installed in 2007 - 2009. The table
below contains the peak participation of meter installations for the pilot. The
Landis + Gyr ALF meter which encompasses the vast majority of the pilot
program installations, exhibited significant fading and/or missing segments in the
LCD display over a period of time, thus impacting the visual readability. As the
pilot program was dismantled and the meter reading returned to normal
operations, meters were exchanged on a periodic or as needed basis.
Meter
Landis + Gyr ALF
Landis + Gyr AX
TOALS

Peak Quantity Installed in
Responsive Pricing and Smart
Metering Pilot Program
1579
98
1677

Quantity Still in
Operation
331
45
376

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 87
Responding Witness: John P. Malloy
Q-87.

Reference the Company’s response to OAG 1-304 [Case No. 2016-00370], which
indicates that 4,181 customers on rates RS and RTOD have enrolled in the AMS
Customer Offering. Provide the number of customers in each category described
who accessed their e-portal by completing the table below.
Customer accessed ePortal once
Customer accessed ePortal more than six times
Customer never accessed ePortal
TOTALS

A-87.

Customer Count

4,181

The Company’s response to AG 1-304 showed there were 4,181 Rate RS, RTOD,
and GS customers participating in the AMS Customer Offering. Therefore, the
numbers in the table below include Rate GS customers as well. Note that there
are customers who have accessed ePortal more than once but fewer than six times,
and those customers are counted in the first entry to ensure the entries total to
4,181. Also note that the second entry includes customers who have accessed
ePortal six or more times, which is the criterion the Companies used to determine
who was an active user.
Customer Count
1,905
1,001

Customer accessed ePortal one to five times
Customer accessed ePortal six or more times
Customer never accessed ePortal
TOTALS

1,275
4,181

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 88
Responding Witness: John P. Malloy
Q-88.

Reference the Companies’ response to Sierra Club 1-32 [Case No. 2016-00370].
The response indicates the Companies defined “active users” as those customers
participating in the AMS Customer Offering who visited the ePortal more than 6
times, and that 36% of the 48% of customers who registered for ePortal access
(17% of AMS offering participants) meet this definition. As the Companies are
well aware, customers who opt-in to an AMS offering are the most engaged and
conservation-conscious customers in the Companies’ base. Yet, the Companies
appear to have assumed that the same 17% of customers in the overall customer
base, who will not express the same level of engagement or conservationconsciousness, will also be active users in the Companies’ calculation of the
ePortal conservation benefit estimate.
a. Describe any adjustment the Companies made in the calculation of the ePortal
conservation benefit estimate to reflect differences between customers
participating in the AMS Customer Offering and the overall base of
customers.
b. Describe the adjustment the Companies believe is reasonable to reflect this
difference. Include in the Companies’ response any research or studies the
Companies used to determine such an adjustment.

A-88.

Note that the Company’s response to SC 1-32 defined an active ePortal user as
someone who “had six or more login events following deployment,” not more
than six as the request above states.
a. The Companies made no adjustment when extrapolating the percentage of
active users in the AMS Opt-In Program to the active user percentage
estimated in the calculation of ePortal benefits included in the AMS Business
Case. However, the Companies used a conservative estimate of three percent
energy savings applied to these customers when the Smart Grid Consumer
Collaborative report referenced in the AMS Business Case supports a 5 to 15
percent savings for active users.
b. The Companies do not believe that any such adjustment is necessary due to
the conservative energy-savings assumptions discussed in part a.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 89
Responding Witness: John P. Malloy
Q-89.

Reference the Companies’ response to OAG 1-306.a [Case No. 2016-00370]. The
Companies provided the survey the Companies used to gather customer feedback
about their experience with the Advanced Meter Service (Email Study #16295).
Provide the results of the survey.

A-89.

The survey report and questionnaire were provided in response to AG 1-306.a.

 Response to AG-2 Question No. 90
Page 1 of 2
Malloy
KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 90
Responding Witness: John P. Malloy
Q-90. Reference the Companies’ response to OAG 1-308.a [Case No. 2016-00370],
describing how the Companies will use the proposed AMS system to localize and
resolve power outages.
a. Describe how the Companies will guard against false-positive outage reports.
b. The OAG understands how the Companies plan to integrate AMS with the
Companies’ OMS systems. In the experience of the OAG’s expert, outage
reports from AMS allow grid operators to understand the area and extent of
customers impacted by an outage, much like OMS does today without AMS.
However, the fault must still be located. Describe how the AMS system will, as
described on AMS Business Case page 155, reduce fault location time by 50%
(from 19.2 minutes on average to 9.6 minutes on average).
c. The Companies claim present value savings from reductions in restoration
time/costs of $3.3 million (AMS Business Case page 155). This appears to be
about the same as the reduction in headcount for linemen/troublemen of about
1. Confirm the Companies will reduce lineman/troubleman headcount by 1 at
full AMF deployment as a result of this AMS capability.
A-90.
a. The Company will guard against false-positive outage reports by coordinating
information from different systems to determine the cause. For example, the
network will be monitored to know if the reason a meter cannot communicate
is because the network, collector, or router is down. Maintenance work on the
system will be coordinated with meter outage reports to know if a meter
reporting an outage is for a known reason.
b. Fault location is determined through using information from multiple systems.
OMS not only knows individual outages but also contains how each meter is
connected to distribution circuits, substation feeders, and transmission. Thus,
as outages occur, the outages can be combined with the network connectivity
data to locate the most likely cause or location of the outage. Today, this
information is obtained when customers call in an outage. With AMS, the meter

 Response to AG-2 Question No. 90
Page 2 of 2
Malloy
will report the outage. The increased number of reports when an outage occurs
increases the ability to locate a fault quicker and more accurately.
c. The Companies’ estimate of $3.3 million in restoration reduction savings is
nominal, not present value. The Companies do not plan to reduce
lineman/troubleman upon full AMS deployment. The savings is attributed to
reduced overtime expense incurred.

 Response to Question No. 91
Page 1 of 2
Malloy
KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 91
Responding Witness: John P. Malloy
Q-91.

Reference the Companies’ response to OAG 1-316 [Case No. 2016-00370],
describing how the Companies calculated ePortal savings as detailed on page 157
of the AMS business case. The OAG’s expert is the author of the Smart Grid
Consumer Collaborative report cited by the Companies in its ePortal benefit
calculation. The OAG expert makes several observations of the Companies’
calculations:
•

The Companies used a total bill reduction to calculate benefits. Actual
economic savings to customers in the long run will be limited to fuel cost
reductions, as reductions in sales volumes will result in $/kWh increases to
recover the Companies’ fixed costs.

•

The Companies assume that 48% of customers will access the ePortal, and
that 36% of these will reduce their energy use, resulting in an “adoption
rate” (customers who use the ePortal to conserve energy) of 17.28% (48%
x 36%). In the research cited, adoption rates of 2% (reference case) to 5%
(ideal case) are indicated.

•

In the research cited, conservation rates of 5% to 15% were reported with
the use of direct, real-time energy usage feedback (i.e., in-home displays).
In the report author’s informed opinion, conservation rates of this size will
not be possible without the use of in-home displays, a high-cost option not
included in the Companies’ AMS proposal.

Recalculate the present value of ePortal benefits using the following assumptions:
a. Fuel cost savings only, 2% adoption rate, 3% energy conservation effect
(OAG most likely case)
b. Fuel cost savings only, 5% adoption rate, 3% energy conservation effect
(OAG ideal case)

 Response to Question No. 91
Page 2 of 2
Malloy
c. Fuel cost savings only, 5% adoption rate, 5% energy conservation effect
(OAG extremely unlikely case)
A-91.

Recalculations are provided below, however the Company disagrees with the
premise of the question and stands by its original calculation. As the ePortal
savings were calculated based on the customer perspective, a reduction in energy
due to access to usage would reduce the total bill.

($Millions)
a.
b.
c.

Nominal
Value
$
5.5
$
13.8
$
23.0

Net Present
Value
$
2.2
$
5.5
$
9.2

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 92
Responding Witness: John P. Malloy
Q-92.

Reference the Companies response to OAG 1-316 [Case No. 2016-00370].
Provide the revenue projections, including MWh volume and prices by year, upon
which the Companies calculated their conservation benefit by year and resulting
in a nominal estimate of $166.3 million. Also describe the revenue projections
(i.e., “residential and small commercial”, etc.). The data provided, in conjunction
with the assumptions provided in the AMS business case, should be sufficient for
the OAG to duplicate the Companies’ estimates.

A-92.

The Companies did not directly use MWh and MW volumes and prices to
calculate the benefit. Refer to the attachment to PSC 2-64, tab “AMSBenefits”,
rows 225-240 for the detailed calculations by year. Note that only residential data
is included in the calculation.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 93
Responding Witness: John P. Malloy
Q-93.

Refer to the Companies’ response to OAG 1-318 [Case No. 2016-00370],
describing how the Companies calculated savings associated with a reduction in
“OK on Arrival” truck rolls as detailed on page 156 of the AMS business case.
The Companies claim present value savings from reductions in OK on Arrival of
$6.9 million. This appears to be about the same as a reduction in headcount for
linemen/troublemen of about 2. Confirm the Companies will reduce
lineman/troubleman headcount by 2 at full AMF deployment as a result of this
AMS capability.

A-93.

The Companies’ estimate of $6.9 million in OK on Arrival savings is nominal,
not present value. The Companies do not plan to reduce lineman/troubleman
headcount as a result of this capability as the savings are expected to be a
reduction in overtime.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 94
Responding Witness: John P. Malloy
Q-94.

Refer to the Companies’ response to OAG 1-320 and 1-321 [Case No. 201600370]. The Companies provided a breakdown of Meter reading savings by year
totaling $203 million over 20 years, and meter services spending totaling $92
million over 20 years
a. Provide 2015 meter reading spending with FERC Uniform System of
Account details.
b. Provide 2015 meter services spending with FERC Uniform System of
Account details.

A-94.
a. Meter Reading
FERC #
Amount
426
583
902
5,007,040
Total
5,007,623
b. Meter Services
FERC #
Amount
426
5,874
586
6,131,842
587
(38,396)
925
(4,043)
926
1,836
Total
6,097,113

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 95
Responding Witness: John P. Malloy
Q-95. Refer to the Companies’ response to OAG 1-323 [Case No. 2016-00370]. Provide
the revenue projections, including MWh and MW volume and prices by year, which
the Companies employed to calculate its non-technical losses benefit estimate by
year and resulting in a nominal estimate of $488.6 million. Also describe each
component of the revenue projections (i.e., “residential and small commercial”,
“large commercial”, “industrial”, etc.) The data provided, in conjunction with the
assumptions provided in the AMS business case, should be sufficient for the OAG
to duplicate the Companies’ estimates.
A-95. The Companies did not directly use MWh and MW volumes and prices to calculate
the benefit. Refer to the attachment to PSC 2-63, tab “AMSBenefits”, rows 243254 for the detailed calculations by year. The revenue used in the calculation is
listed by rate type on tab “KY Detail Electric Revenues”.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 96
Responding Witness: John P. Malloy
Q-96.

Refer to the Companies’ response to OAG 1-330 [Case No. 2016-00370]. The
Companies indicate that no affiliated utilities have executed a system-wide
conversion to AMI meters. The OAG is aware that PPL Electric Utilities Corp
filed an application with the Pennsylvania PUC for approval of its smart meter
implementation plan on or around June 30, 2014 in case M-2014-2430781. The
OAG was unable to locate anything other than the cover page and certificate of
service on the Pennsylvania PUC website. Provide the entire application and
smart meter implementation plan submitted by PPL Electric Utilities Corp to the
Pennsylvania PUC in case M-2014-2430781, including any cost-benefit analyses
which may have accompanied the application and implementation plan.

A-96.

See http://www.puc.pa.gov//pcdocs/1296056.pdf, Section IX, page 51 of the PPL
Electric Utilities Corporation Smart Meter Technology Procurement and
Installation Plan discusses benefits. Costs are discussed in Section X, page 54.

 Response to AG-2 Question No. 97
Page 1 of 2
Malloy
KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 97
Responding Witness: John P. Malloy
Q-97.

Refer to the Companies’ response to OAG 1-342 [Case No. 2016-00370], in
which the Companies state the hardware, firmware, and software associated with
the Companies’ proposed AMS implementation is “aligned with” NIST
Interoperability Standards Release 3.0. The OAG notes that “alignment” is not
the same as “compliance”. NIST Interoperability Standards Release 3.0 describes
72 standards on pages 59-120. Identify each standard with which the Companies’
proposed AMS implementation does not comply. For each non-compliant
standard:
a. Describe how the Companies’ proposed AMS implementation is out of
compliance with the standard.
b. Provide a justification, if any, as to why the Companies are proposing AMS
designs not in compliance with the standard.
c. For standards with no justification, describe how the Companies are willing
to modify their AMS design to comply with the standard.
d. For standards with no justification, estimate the incremental cost of the
compliance modifications

A-97.

The portion of the NIST Interoperability Standards Release 3.0 cited in the
request does not contain binding or enforceable standards for smart-grid devices
or related equipment. Instead, it is a list of evolving standards, practices, and
procedures—hence “Release 3.0”—developed by government and industry
sources, including the Companies’ proposed AMS vendor, Landis+Gyr. The
cited list of standards, practices, and procedures is not enforceable by NIST or
any other entity; rather, it is a list of standards NIST believes can be implemented
related to smart-grid interoperability and related matters. Indeed, a number of the
listed standards, practices, and procedures do not apply to AMS design at all. For
example, number 39 on the list, “NAESB RE Q-22, Third Party Access to Smart
Meter-based Information Business Model Practices CoS,” is a document that
“establishes voluntary Model Business Practices for Third Party access to Smart
Meter-based information” that are “intended only to

 Response to AG-2 Question No. 97
Page 2 of 2
Malloy
serve as flexible guidelines rather than requirements ….” Such practices do not
apply to AMS design per se, but rather to business practices.
In addition, there is no certifying body to which one could go to verify compliance
with the cited standards to the extent they could be applicable.
That is why the Companies have stated that their proposed AMS deployment is
in alignment with the NIST Interoperability Standards Release 3.0; not all of it
could apply to the AMS deployment, and there is no certifying entity that could
verify compliance with any of the proposed standards.
But the Companies would note that Landis+Gyr (L+G) has participated in, and
contributed to writing the standards proposed by, the Smart Grid Interoperability
Panel (SGIP) for the areas where L+G has relevant solutions (metering, networks,
Meter Data Management System). Suppliers must choose to align with the
SGIP’s interoperability standards. L+G has chosen to align to the standards,
which are also important components of the cited NIST standards.
Furthermore, L+G has deployed approximately 25 million meters across North
America. They have vast experience with meters, networks, and systems which
help utilities operate and provide services to their customers. They are a solid
company backed by Toshiba Corporation and work within the industry to not only
align with standards but help create the standards to advance smart grid
infrastructure.

 Response to Question No. 98
Page 1 of 5
Malloy
KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 98
Responding Witness: John P. Malloy
Q-98.

Refer to the Companies’ response to OAG 1-343 [Case No. 2016-00370], which
references Appendix A-2 of Exhibit JPM-1 “Application Landscape”.
a. Identify the system or application on this page in which meter data is
translated into billing data, and eventually into customer bills.
b. Identify vendors, names, versions, and other descriptive information on
software or applications the Companies have, or plan to implement, to bill
customers using AMS data.
c. Describe the capabilities of each software or application identified above.
d. If the capabilities described above do not include the ability to bill rates with
peak demand response features, such as Critical Peak Price and Peak Time
Rebate, describe the required software modifications and incremental costs
required to do so.

A-98.
a. The L+G Meter Data Management System (MDMS) Gridstream will receive
interval data and register reads from the L+G Command Center Head End.
This data will be then translated into billing determinants within the MDMS,
and those billing determinants will be sent to SAP. SAP will then apply the
appropriate rates to the billing determinants to calculate the actual billing
amounts
b. Command Center – Version 6.x or 7.x
Advanced Security - Part of Command Center
Gridstream Meter Data Management System (MDMS) – Gridstream L&G
MDMS version 3.7
Meter Asset Management System (MAM) Radian WECO Watt-Net Plus –
Watt-Net Plus version 2.6

 Response to Question No. 98
Page 2 of 5
Malloy
Meter Operations Center (MOC) Bit Stew Mix Core – Mix Core version 10
c. Command Center
Command Center is the browser-based operating software for Gridstream RF
and PLC networks. It installs seamlessly, or can run on hosted servers, and
provides a secure platform for data and system management throughout the
utility. Reports are tailored for use by billing, finance, customer service,
operations, distribution planning and engineering departments. Multiple
integration partners and cross-platform functionality ensure Command Center
will integrate into the entire business.
Key features include:
•
•
•
•
•
•
•

Support for multiple applications, including AMI and personal
energy management
Reliability indices reporting capabilities
Power interruption reporting
System diagnostics
Remote programming of time-based billing structures
Tamper detection
Available hosting service reduces demands on utility staff

Advanced Security
Advanced Security means that security certificates are created and assigned
for each endpoint rather than a single certificate for all communications. This
feature significantly reduces the risk of a successful cyber-attack gaining
over-the-air control capabilities of all meters and infrastructure, therefore
more effectively isolating the risk of a mass event. Advanced security
protocols align with industry best practices as recommended by the National
Institute of Standards and Technology Interagency Report (NISTIR) which
states:
“Where meters contain cryptographic keys for authentication, encryption, or
other cryptographic operations, a key management scheme must provide for
adequate protection of cryptographic materials, as well as sufficient key
diversity. That is, a meter, collector, or other power system device should not
be subject to a break-once break-everywhere scenario, due to the use of one
secret key or a common credential across the entire infrastructure. Each
device should have unique credentials or key material such that compromise
of one device does not impact other deployed devices.” [1]

[1]

Source: section 4.1.3, Pg. 219, NISTIR 7628.

 Response to Question No. 98
Page 3 of 5
Malloy

Gridstream Meter Data Management System
Gridstream MDMS
Gridstream MDMS is a standards-based system designed to rigorously
process and prepare data for a variety of utility programs and operations.
This single, unified system consolidates metering, consumption and related
data from all read sources in a centralized system of record repository. It
standardizes data for use according to customer specified rules. Using
international and industry standards, it interconnects field metering systems
with a broad range of enterprise applications. Its analytic processes prepare
data for a wide range of utility operations.
Features include:
•

•

•

•

•

•

•

Data Collection & Synchronization: Standards-based interfaces
enable data to be consumed by the Gridstream MDMS from smart
meter systems or smart grid devices. The MDMS then processes,
formats and places the data in the proper context for any utility back
office system
Distribution Network & Power Quality: The Gridstream MDMS
maintains the network connectivity model; it enables load mapping
and stores non-billing data such as voltage and amperage to provide
granular visibility into the smart grid infrastructure.
Validation, Estimation, Editing (VEE) Engines: Powerful analytic
engines capable of processing hundreds of millions of register and
interval reads to bill quality.
Exception Management: The workflows within the Gridstream
MDMS focus on efficient exception management and the remediation
of events related to the VEE process.
Billing Extracts: The Gridstream MDMS provides cleansed, framed
billing determinants for each rate structure to the utility CIS and/or
Billing applications on the billing cycle days.
Analytics & Reports: The analytics and reports within the
Gridstream MDMS ensure current and valid, data is correlated using
embedded business logic to turn data into knowledge.
Virtual & Net Metering: The virtual and net metering capability
within the Gridstream MDMS provides the flexibility to create both
virtual meters and virtual channels to support accurate billing for
complex metering situations.

 Response to Question No. 98
Page 4 of 5
Malloy
Meter Asset Management System (MAM) Radian WECO Watt-Net Plus
WATT-Net Plus is the premier asset and smart grid device management
database software solution for electric and gas utilities. WATT-Net Plus is an
innovative, industry-targeted solution with a unique testing approach that is
full featured and highly configurable to meet your business process
requirements.
WATT-Net Plus is the most comprehensive device management software
package available that offers powerful functionality and ease of use,
specifically designed for the metering industry. WATT-Net Plus is the
evolution of the WECO industry de facto standard, WATT-Net™ — shop
automation and data management software. Building on the WATT-Net
legacy of over 900 customers worldwide, WATT-Net Plus expands the
software to an enterprise level with additional advanced features and
capabilities.
With the demands of AMI, customer requirements for more real-time data
and enterprise connectivity increased dramatically. To answer this growing
need, WNP uses the AMSLLC Listener™, the newest in enterprise
integration technology, to manage all data flow to and from the WNP System,
freeing WNP to do what it does best — manage the meter operation process.
WATT-Net Plus Core Features Include:
•

•

•
•

•

A Broad Range of Utility Devices - Electric Meters (KWH, KW),
Reference Standards, Current Transformers, Potential Transformers,
and Testboards.
Support of AMI Configuration Test Points - AMI Impedance Testing,
AMI Configuration Testing, KWH Automated Testing, KW
Automated Testing, KW/Runtime Gangboard Automation, Current
Transformer Testing, Potential Transformer Testing
Security - Roles Based Security, Windows Authentication, LDAP
Support
Administration - Purchase Order Tracking, Contractor and
Manufacturer Test Data Import, Tamper Case Documentation, Sticky
Notes, Test Cards, and more.
Reporting - Device Listing, Counts, and StatisticsAMI and Smart Grid
Support - AMR/AMI Module Traceability, Software, Firmware, and
Program ID Traceability

 Response to Question No. 98
Page 5 of 5
Malloy
•
•
•
•
•
•
•
•

New Device Management
New Device Sample Management
Sample/Periodic Test Management, Testing and Reports, Device
Configuration, and Site Premise Management
Equipment Editors
Equipment Tracking
Audit and Certification Traceability
Programmable State Tracking
Business Rules Engine - Meter Test Processing

Meter Operations Center (MOC) Bit Stew Mix Core
Bit’s Stew MIx Core is an Intelligent Data Integration platform that automates
the modelling, mapping and ingestion of data to a semantic model enabling
rapid analytics and visualization solutions for your data-driven projects. The
platform will quickly integrate data from disparate sources to provide
operational intelligence in real time. It uses Machine Intelligence to
automatically identify, model, map and ingest data from connected devices
and systems. A federated architecture supports analytics from control systems
to cloud environments placing actionable intelligence for operators,
engineers, and data teams through the creation of workbenches to analyze and
visualize the data.
For utility applications of the platform, MIx Core leverages an IEC Common
Information Model (CIM)-based data model with extensions to support
utility’s needs. Additional entity types can be quickly added without any reindexing.
The MIx Core platform solves the data integration problem across all the
connected systems, devices and external sources. It can operate on edge
devices such as gateways and routers, across any industry, from the data
center to the cloud. The MIx Core platform was built on Bit Stew’s proven
ten-year experience integrating and managing industrial data across complex
environments.
d. The applications listed above all have the capabilities to bill the rates
described in this question. The complexity of the actual rate design will
determine if configuration or code development is required to facilitate the
data requirement. Configuration is primarily table driven or simpler changes
that are made to an application to derive results. Code development is usually
much more complex changes that are needed when base application code does
not support design. Therefore, it is not possible to provide a cost estimate
without a full understanding of the final rate design.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 99
Responding Witness: Lonnie E. Bellar
Q-99.

Regarding response to KIUC 1 – 34, provide the attached spreadsheet in
electronic form.

A-99.

See the response to KIUC 2-15.

 Response to AG-2 Question No. 100
Page 1 of 3
Bellar
KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 100
Responding Witness: Lonnie E. Bellar
Q-100. Regarding response to KLC 1 – 45, provide the following information:
a. Detailed activities and costs for Mill Creek 2 generation outage during test
year.
b. Detailed activities and costs for Trimble County 1 generation outage during
test year.
c. Detailed activities and costs for all combustion turbine outages during test
year.
d. Provide how major combustion turbine outage activities, including combustor
inspections, are scheduled for all combustion turbines and combined cycle
unit combustion turbines.
e. For each combustion turbine, including those in combined cycle units, explain
if outage activities scheduled are based on hours or equivalent starts or both.
f. For each combustion turbine, including those in combined cycle units,
provide the number of operating hours or equivalent starts between each
major outage activity.
g. For each combustion turbine, including those in combined cycle units, explain
whether current forecast shows major outage activity based on hours or
equivalent starts.
h. For each combustion turbine, including those in combined cycle units,
provide current 10 year forecast of annual run hours and equivalent starts.

 Response to AG-2 Question No. 100
Page 2 of 3
Bellar
A-100.
a. KU has no ownership of Mill Creek 2.
b. KU has no ownership of Trimble County 1.
c. See attached.
d. Major combustion turbine outage activities are driven by unit operation,
measured through starts, factored starts (“FS”), run hours, or equivalent
operating hours (“EOH”), depending on the unit. These activities are
scheduled by incorporating expected run hours and starts with historical
operational data to determine the planned timing of an outage need in
accordance with the manufacturer’s recommended maintenance interval, and
aligning that need within the Companies’ spring or fall outage seasons.
e. See response to part f.
f. For the E.W. Brown combustion turbines (“CTs”), the major inspection
interval is 24,000 EOH. Each start adds 20 EOH, and each run hour adds 1
EOH. Operating units on fuel oil (where applicable) incurs 50% additional
EOH per hour or start.
For the Paddy’s Run 13 CT, the hot gas path inspection interval is 25,000
EOH, and the major inspection interval is 50,000 EOH. Each unit start adds
10 EOH, and each run hour adds 1 EOH.
For the Trimble County CTs, the hot gas path inspection interval is 900
factored starts, the major inspection interval is 2,400 actual starts, and the
rotor inspection interval is 5,000 factored starts. The calculation of factored
starts from actual starts varies based on start type (conventional vs. quickstart), load achieved during start cycle, and ambient temperature, and the
calculation varies for each inspection type. The contribution toward factored
starts per actual start varies from 0.5 to 4.0 factored starts per actual start.
For Cane Run 7, the combustor inspection interval is 16,600 run hours or
1,200 starts, the hot gas path inspection interval is 33,200 run hours or 1,200
starts, and the major inspection interval is 66,400 run hours or 2,400 starts
(for each case, whichever interval occurs first).
Units may accrue additional hours or starts for other reasons, such as failed
startup attempts and unit trips.
g. For the CTs at E.W. Brown and Paddy’s Run, the current forecast shows
major outage activity based on EOH. For the CTs at Trimble County, the

 Response to AG-2 Question No. 100
Page 3 of 3
Bellar
h. current forecast shows major outage activity based on starts or FS, dependent
upon the outage activity. For Cane Run 7, the current forecast shows major
outage activity based on run hours.
i. See the tables below. Data reflects averages of similar units where applicable.
Run Hours
Forecast
Unit(s)
E.W. Brown 5
E.W. Brown 6-7
E.W. Brown 811
Paddy's Run 13
Trimble County
5-10
Cane Run 7
Start Forecast
Unit(s)
E.W. Brown 5
E.W. Brown 6-7
E.W. Brown 811
Paddy's Run 13
Trimble County
5-10
Cane Run 7

2017
349
472

2018
667
593

2019
291
517

2020
151
334

2021
153
346

2022
171
455

2023
128
369

2024
111
309

2025
138
373

2026
114
305

147

198

143

72

63

87

62

74

95

39

1407

1328

1219

1048

836

683

1172

933

1083

1272

1267

1535

1239

865

827

929

914

688

774

706

7351

7435

6900

6111

5937

5696

3957

4237

4030

4243

2017
41
53

2018
62
71

2019
30
52

2020
26
47

2021
26
48

2022
26
65

2023
22
55

2024
19
49

2025
23
49

2026
20
51

20

24

17

16

13

13

11

13

15

8

203

200

156

131

106

91

149

110

141

155

145

155

139

120

117

120

125

97

108

104

32

39

42

111

125

146

174

228

241

231

 Attachment to Response to AG-2 Question No. 100(c)
Page 1 of 1
Bellar
0172 - CANE RUN CC GT
Account
Expenditure Type
552100 0301 - O/S - OTHER-LABOR-3RD PARTY
552100 0303 - O/S - MATERIAL & EQUIPMENT
553010 0301 - O/S - OTHER-LABOR-3RD PARTY
553010 0303 - O/S - MATERIAL & EQUIPMENT
554100 0301 - O/S - OTHER-LABOR-3RD PARTY
554100 0303 - O/S - MATERIAL & EQUIPMENT

Amount
715,000
684,000
360,000
240,000
363,000
243,000

5636 - E W BROWN COMBUSTION TURBINE UNIT 6
Project Description
Account
Expenditure Type
BRCT6 C INSPECTION 2018
553010 0301 - O/S - OTHER-LABOR-3RD PARTY
BRCT6 C FSI's 2018
553010 0301 - O/S - OTHER-LABOR-3RD PARTY
BRCT6 A INSPECTION
553010 0301 - O/S - OTHER-LABOR-3RD PARTY
CT ENVIRONMENTAL TEST
553010 0301 - O/S - OTHER-LABOR-3RD PARTY
BRCT6 A INSPECTION
553010 0427 - PM - OTHER

Amount
158,100
316,200
49,000
45,000
3,000

5637 - E W BROWN COMBUSTION TURBINE UNIT 7
Project Description
Account
Expenditure Type
CT7 OUTAGE (A INSP)
553010 0301 - O/S - OTHER-LABOR-3RD PARTY

Amount
29,760

5638 - E W BROWN COMBUSTION TURBINE UNIT 8
Project Description
Account
Expenditure Type
553010 0301 - O/S - OTHER-LABOR-3RD PARTY
BRCT 8 A INSPECTION

Amount
65,000

5641 - E W BROWN COMBUSTION TURBINE UNIT 11
Project Description
Account
Expenditure Type
BRCT11 C INSPECTION 2018
553010 0301 - O/S - OTHER-LABOR-3RD PARTY

Amount
343,000

Project Description
HF Unit 1 ANNUAL OUTAGE

5693 - HAEFLING UNIT 1
Account
Expenditure Type
553010 0301 - O/S - OTHER-LABOR-3RD PARTY

Amount
18,000

Project Description
HF Unit 2 ANNUAL OUTAGE

5694 - HAEFLING UNIT 2
Account
Expenditure Type
553010 0301 - O/S - OTHER-LABOR-3RD PARTY

Amount
18,000

Project Description
CR7 FALL OUTAGE 2017
CR7 FALL OUTAGE 2017
CR7 FALL OUTAGE 2017
CR7 FALL OUTAGE 2017
CR7 FALL OUTAGE 2017
CR7 FALL OUTAGE 2017

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 101
Responding Witness: John K. Wolfe
Q-101. Regarding the response to AG1 – 11, describe in detail how the DA initiative will
be used to improve reliability on each of the worst performing circuits.
A-101. The DA initiative will improve reliability on worst performing circuits where it
is implemented by sectionalizing and isolating faults to minimize sections of
impacted customers, thus reducing reliability impacts of mainline outages. This
capability maintains service to customers outside of the isolated section of the
distribution circuit. Speed of service restoration to impacted customers will be
improved due to immediate availability of fault location information from the DA
reclosers.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 102
Responding Witness: John K. Wolfe
Q-102. Regarding the response to AG1 – 371, provide the following:
a. Detailed description of each time in the past 5 years a portable transformer
was installed, including why, the cost, the time involved for the temporary
installation, effort and action required to locate repair or replacement parts,
permanent repair or replacement solution implemented, and the time to
provide a permanent replacement or repair. Description for each event should
also include the cause and the number of customers affected and how they
were affected.
b. Please describe in detail all spare substation transformers maintained.
c. Please describe any and all mobile “substations” (transformers and associated
equipment) the company has access to or owns for substation transformer
failures.
d. Describe in detail all preventative maintenance and inspection activities the
company currently implements to identify potential substation transformer
failures.
e. Detailed description of any outage related to substation transformer failure
over the past 5 years and subsequent actions taken to prevent recurrence.
A-102.
a. See attached.
b. See attached.
c. See attached.
d. See attached.
e. See attached.

 AG 1-371 Q102(a)
KU Portable Installation Details
2012-2016

Substation
Portable - P002
Waco

Reason for Installation

Customers
Affected

Impact to
Customers

0

No Impact

Length of
Outage
(minutes)

Approximate Cost Installation
of Installation
Date
Removal Date

Details

Greensburg

Maintenance

0

No Impact

0 $

40,000

5/10/2012

Sardis

Maintenance

0

No Impact

0 $

40,000

5/23/2012

Kenton

Maintenance

0

No Impact

0 $

30,000

8/23/2012

5/10/2012 Planned transformer upgrade to larger capacity.
Portable installed to serve distribution load while transformer
5/23/2012 maintenance was performed to prevent gassing.
Portable was installed to serve distribution load during proactive
8/23/2012 transformer replacement due to moisture.
Portable was installed to allow for Load Tap Changer replacement on
9/11/2012 Transformer.
Portable was installed to complete repairs to station following
previous equipment failure. At time of failure portable was installed
for maintenance at Kenton. Station was put in a position to return
9/20/2012 service until Portable was available to do complete repair.

Transformer Upgrade

0 $

40,000

3/20/2012

Carlisle

Equipment Failure

0

No Impact

0 $

40,000

9/11/2012

Wilmore

Maintenance

0

No Impact

0 $

30,000

11/11/2012

Falmouth

Capital Construction Support

0

No Impact

0 $

50,000

11/27/2012

Lynch
Eastview
Hodgenville
Munfordville

Capital Construction Support
Maintenance
Maintenance
Maintenance

0
0
0
0

No Impact
No Impact
No Impact
No Impact

0
0
0
0

$
$
$
$

75,000
40,000
40,000
40,000

4/29/2013
7/29/2013
8/5/2013
8/19/2013

Vine Grove
Totz
Vine Grove

Maintenance
Capital Construction Support
Maintenance

0
0
0

No Impact
No Impact
No Impact

0 $
0 $
0 $

40,000
30,000
30,000

9/12/2013
9/18/2013
11/6/2013

Georgetown

Capital Construction Support

0

No Impact

0 $

40,000

11/11/2013

Cumberland

Maintenance

0

No Impact

0 $

50,000

11/29/2013

Mount Vernon
Warsaw East

Maintenance
Maintenance

0
0

No Impact
No Impact

0 $
0 $

40,000
30,000

2/25/2014
7/21/2014

Vine Grove

Maintenance

0

No Impact

0 $

40,000

9/15/2014

Liberty

Capital Construction Support

0

No Impact

0 $

30,000

9/25/2014

Atoka

Capital Construction Support

0

No Impact

0 $

40,000

10/20/2014

Cynthiana

Capital Construction Support

0

No Impact

0 $

40,000

11/12/2014

Carlisle

Maintenance

Pocket

Equipment Failure

Warsaw East

Capital Construction Support

Bonnieville

Transformer Failure

0
249
0

300

No Impact
Outage
No Impact

outage

Action to restore system to normal
Installed new transformer
Preventive Maintenance
Replaced Transformer Proactively
Load Tap Changer was replaced.

Completed repairs to failed
equipment and station equipment.

Transformer bushings were found to be leaking. Portable was installed Bushings were replaced with in stock
bushings.
11/19/2012 to serve substation load during transformer bushing replacement.
1/7/2013 Portable was installed to support capital upgrades to substation.
Portable installed to serve distribution load during significant work on
7/11/2013 Transmission system in station.
8/5/2013 Transformer and Load Tap Changer Maintenance
8/19/2013 Transformer and Load Tap Changer Maintenance
9/6/2013 Transformer and Load Tap Changer Maintenance
9/17/2013 Load Tap Changer repairs due to failed components.
10/31/2013 Portable installed to support rebuild of substation
11/8/2013 Load Tap Changer repairs due to failed motor mounting.
Planned capital replacement of voltage regulators. Portable installed
11/27/2013 to serve distribution load during replacement
1/13/2014 Load Tap Changer repairs due to failed components.
Station was returned to service following an outage while portable
3/25/2014 was installed to make complete repairs.
7/23/2014 Preventive Maintenance on Load Tap Changer.
9/17/2014 Load Tap Changer repairs due to failed motor
Capital improvements to metering and recloser. Portable installed to
10/6/2014 serve distribution load during replacement.
Capital improvements to substation. Portable installed to serve
11/10/2014 distribution load during station upgrade.
Capital improvements to substation. Portable installed to serve
12/5/2014 distribution load during station upgrade.

0 $

40,000

3/12/2015

92 $

75,000

4/10/2015

0 $

30,000

6/24/2015

Proactive replacement of transformer from preventive maintenance
activities. Portable installed during preventive maintenance and
4/10/2015 remained through transformer replacement.
Equipment failure in station. Portable was installed to support station
5/22/2015 repairs.
Planned capital replacement of Load Tap Changer. Portable was
7/16/2015 installed to serve distribution load during replacement.

56 $

50,000

7/28/2015

Transformer failed. All customers were restored and Portable was
8/3/2015 installed during transformer replacement for distribution reliability.

Completion of capital upgrades
Completion of capital upgrades
Preventative Maintenance
Preventative Maintenance
Preventative Maintenance
Replaced gears with in stock
components.
Rebuilt Substation.
Repaired parts in house
Purchased and replaced regulators.
Replaced gears with in stock
components.
Material was procured and installed.
Preventive Maintenance
Replaced motor with in stock
components.
Replaced metering and recloser.
Purchased material and completed
station upgrade.
Purchased and replaced regulators.

Replaced transformer with available
spare.
Evaluation and repair of station.
Purchased and replaced Load Tap
Changer.

Replaced Transformer

Attachment to Response to AG-2 Question No. 102(a)
Page 1 of 2
Wolfe

 AG 1-371 Q102(a)
KU Portable Installation Details
2012-2016

Substation

Reason for Installation

Customers
Affected

Impact to
Customers

Length of
Outage
(minutes)

Approximate Cost Installation
of Installation
Date
Removal Date

Details

Action to restore system to normal

Portable - P002

New Haven

Capital Construction Support

0

No Impact

0 $

30,000

8/17/2015

8/26/2015

Warsaw

Maintenance

0

No Impact

0 $

30,000

10/5/2015

11/25/2015

Sonora

Maintenance

0

No Impact

0 $

30,000

6/2/2016

6/13/2016

Springfield

Maintenance

0

No Impact

0 $

40,000

6/14/2016

6/17/2016

Munfordville

Maintenance

0

No Impact

0 $

50,000

10/11/2016

10/27/2016

Kentenia

Capital Construction Support

0

No Impact

0 $

30,000

10/27/2016

11/8/2016

Munfordville
Portable - P003

Transformer Failure

579 $

50,000

12/20/2016

AO Smith

Capital Construction Support

0

No Impact

0 $

50,000

6/5/2012

Carntown

Capital Construction Support

0

No Impact

0 $

50,000

7/24/2012

Sharon
Delaplain

Maintenance
Maintenance

0
0

No Impact
No Impact

0 $
0 $

50,000
50,000

3/15/2013
4/12/2013

Wedonia

Capital Construction Support

0

No Impact

0 $

50,000

9/2/2013

Adams

Capital Construction Support

0

No Impact

0 $

50,000

10/31/2013

Versailles West

Equipment Failure

0

No Impact

0 $

50,000

1/13/2014

Versailles West

Equipment Failure

0

No Impact

0 $

40,000

4/3/2014

Woodlawn

Maintenance

0

No Impact

0 $

50,000

4/10/2014

Delaplain

Capital Construction Support

0

No Impact

0 $

50,000

4/17/2015

Bardstown City

Equipment Failure

1

Outage

391 $

50,000

6/11/2015

Lockport

Capital Construction Support

0

No Impact

0 $

50,000

7/23/2015

Parkers Mill

Capital Construction Support

0

No Impact

0 $

50,000

10/26/2015

Lakeshore

Capital Construction Support

0

No Impact

0 $

50,000

9/26/2016

5500

Outage

Planned capital improvements. Portable installed to serve distribution
load during improvements.
Portable was installed to support distribution load during corrective
maintenance of transmission switch.
Capital improvements to substation. Portable installed to serve
distribution load during station upgrade.
Transformer bushing replacement. Portable was installed to serve
distribution load while bushings were replaced.
Preventive Maintenance on transformer. Portable was installed to
serve distribution load during maintenance.
Capital improvements to substation. Portable installed to serve
distribution load during station upgrade.

Purchase and installed oil filtration
system on transformer to improve life
of transformer.
Corrective Maintenance
Installed Load Tap Changer filtering
system.
Preventive Maintenance
Preventive Maintenance

Replaced
Replaced Transformer with available
1/3/2016 Transformer failed. Portable installed during transformer replacement. spare.

Capital upgrade to substation due to load growth. Portable installed to
7/24/2012 serve distribution load during project.
Portable was installed to serve distribution load while transformer was
9/26/2012 returned to factory for warranty repairs.
Load Tap Changer replacement. Portable installed to serve distribution
4/12/2013 load during load tap changer replacement.
6/13/2013 Preventive maintenance on Load Tap Changer.

Installed new transformer and
upgraded substation equipment.
Sent transformer to factory and
return and install.
Purchased and Installed new Load Tap
Changer.
Preventive Maintenance

Capital upgrades to Flemingsburg. Portable was installed at Wedonia
9/25/2013 to serve distribution load during the Flemingsburg upgrade.
Portable was installed to support replacement of station upgrades for
12/3/2013 reliability.
Failed parts in load tap changer. Portable installed to support
3/4/2014 replacement of failed equipment.
Failed parts in load tap changer. Portable installed to support
4/10/2014 replacement of failed equipment.
Portable was installed to serve distribution load during planned
4/24/2014 transmission line maintenance.

Completion of substation upgrade
Flemingsburg.

Capital upgrade to station to support customer expansion. Portable
6/9/2015 installed to serve distribution load during expansion project.
Transformer bushing failure. Portable was installed to serve
6/17/2015 distribution load during transformer bushing replacement.
Capital improvement to station. Portable installed to serve distribution
8/13/2015 load during capital project to install transrupter.
Capital improvements to station. Portable installed to serve
1/8/2016 distribution load during Transmission capital improvements.
Portable was installed to serve distribution load during substation
10/17/2016 expansion.

Replaced substation equipment.
Installed new parts in Load Tap
Changer.
Installed new parts in Load Tap
Changer.

Completion of expansion.
Replaced bushings with stock
bushings.
Installed new equipment.
Installed new equipment.
Completion of substation expansion.

Attachment to Response to AG-2 Question No. 102(a)
Page 2 of 2
Wolfe

 location
Pineville Substation Department
Pineville Substation Department
Pineville Substation Department
Pineville Substation Department
Pineville Substation Department
Pineville Substation Department
Pineville Substation Department
Pineville Substation Department
Pineville Substation Department
Pineville Substation Department
Pineville Substation Department
Pineville Substation Department
Pineville Substation Department
Pineville Substation Department
Pineville Substation Department
Pineville Substation Department
Pineville Substation Department
Pineville Substation Department
Pineville Substation Department
Pineville Substation Department
Bear Track
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Earlington Substation Department
Corning 12kV

equip_category
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS

equip_type
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
WithLTC
WithLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
WithLTC
WithLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
WithLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
WithLTC
NonLTC
WithLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
WithLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
WithLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC

manufacturer
Howard Industries
Central Moloney
Central Moloney
Central Moloney
General Electric
General Electric
General Electric
General Electric
General Electric
Allis Chalmers
General Electric
General Electric
Westinghouse
General Electric
General Electric
Westinghouse
General Electric
General Electric
General Electric
General Electric
General Electric
Westinghouse
Howard Industries
Pennsylvania
Howard Industries
Howard Industries
Howard Industries
Central Moloney
Central Moloney
Central Moloney
General Electric
General Electric
Allis Chalmers
General Electric
General Electric
Westinghouse
Kuhlman
Westinghouse
General Electric
Westinghouse
Allis Chalmers
General Electric
General Electric
General Electric
General Electric
General Electric
Howard Industries
Westinghouse
General Electric
General Electric
General Electric
Westinghouse
General Electric
General Electric
General Electric
Westinghouse
Kuhlman
General Electric
Westinghouse
General Electric
Westinghouse
General Electric
General Electric
Westinghouse
General Electric
General Electric
General Electric
General Electric
Solomon
General Electric
Interstate
General Electric
Westinghouse
Westinghouse
Westinghouse
General Electric
Moloney
General Electric
General Electric
Westinghouse
General Electric
Westinghouse
General Electric
Westinghouse
General Electric
ABB
General Electric
General Electric
General Electric
General Electric
Howard Industries
ABB

equip_no
TX000138
TX000063
TX000062
TX000061
M0038
C0283
C0284
0931
0930
C0410
0947
0271
B0219
C0282
0980
B0270
C0413
W0074
W0075
M0013
T0498
B0234
KT0041
TX000080
TX000069
TX000068
TX000067
TX000060
TX000059
TX000058
W0244
W0260
W0103
W0149
W0273
C0333
S0061
B0316
W0346
W0200
C0382
W0248
W0348
W0347
W0233
W0349
KT0007
C0399
W0234
C0303
C0302
W0154
W0209
W0194
W0287
W0187
B0467
W0286
W0263
B0145
B0075
W0265
W0275
C0376
W0288
C0356
W0236
W0235
W0292
W0274
S0013
C0357
C0375
C0374
W0186
B0146
KT0003
C0301
W0123
W0334
W0345
C0170
W0225
W0184
B0147
S0014
C0285
C0156
C0045
W0266
KT0018
C0536

serial_no
3793735015
CM113469803
CM113469902
CM113469801
F-958252
B532692
B532693
8637565
8637564
4069800
C-157165
7082652
7350371
B532691
C860337
6991859
F960658
8683602
8683310
F50643365P
5516754
6534513
295656-4210
R-08570-1-2
3368344913
3368314913
3368304913
CM113469903
CM113469901
CM113469802
E690729B
E695140B
2311818
C184362
F958818A
6533827
341534-04-1
PBR45762
H881663B
6543895
3515629
E691133A
H881854B
H881854A
E690486A
H881854C
488211-4207
6997094
E690486B
8632635
8632637
3773007
C862379
C861434
F962821B
6534013
241504-94-1
F962821A
PBR-88822
B311707
3164026
F53519765P
F958818C
63F9402
F961821C
E37979761P
E690486D
E690486C
F961615B
F958818B
98K7189
E37979961P
63F9401
63F9400
6533937
B311708
CM106524002
8632631
B343668
UCV63970101
H881663A
4087262
C859956C
6533831
B311709
SLB5024-001T
B532694
7529143
6337148
F53519865P
260661-2508
UCB2491-3

operating_class
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution

owner
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU

mfg_date
12/1/2015
1/1/2014
1/1/2014
1/1/2014
1/1/1967
1/1/1951
1/1/1951
1/1/1950
1/1/1950
1/1/1966
1/1/1954
1/1/1942
1/1/1956
1/1/1951
1/1/1959
1/1/1961
1/1/1967
1/1/1944
1/1/1950
1/1/1965
1/1/1937
1/1/1956
11/1/2010
4/1/2014

1/1/2014
1/1/2014
1/1/2014
8/1/1963
1/1/1965
1/1/1950
1/1/1955
1/1/1967
1/1/1953
3/1/2005
1/1/1967
1/1/1985
1/1/1958
1/1/1963
2/1/1964
1/1/1985
1/1/1985
1/1/1963
1/1/1985
10/1/2007
1/1/1965
1/1/1963
1/1/1947
1/1/1947
1/1/1968
1/1/1958
1/1/1958
1/1/1968
1/1/1956
1/1/1994
1/1/1968
1/1/1965
1/1/1950
1/1/1942
1/1/1965
1/1/1967
1/1/1963
1/1/1968
1/1/1961
1/1/1963
1/1/1963
5/1/2010
1/1/1967
1/1/1998
1/1/1961
1/1/1963
1/1/1963
1/1/1956
1/1/1950
2/1/2007
1/1/1947
1/1/1953
1/1/1980
1/1/1985
1/1/1948
1/1/1962
1/1/1955
1/1/1950
1/1/1999
1/1/1952
1/1/1947
1/1/1940
1/1/1965
9/1/2008
1/1/1997

operation_center
Pineville
Pineville
Pineville
Pineville
Pineville
Pineville
Pineville
Pineville
Pineville
Pineville
Pineville
Pineville
Pineville
Pineville
Pineville
Pineville
Pineville
Pineville
Pineville
Pineville
Richmond
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Earlington
Danville

substation_crew_site
PN
PN
PN
PN
PN
PN
PN
PN
PN
PN
PN
PN
PN
PN
PN
PN
PN
PN
PN
PN
DV
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
EA
DV

position_operating_class
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution

h_voltage_rating
34500
34500
34500
34500
67000
67000
67000
34500
34500
67000
65550
69000
69000X34500
67000
67000
67000
67000
33000
33000
67000
66000
69000X34500
69000
34500
34500
34500
34500
34500
34500
34500
67000
67000
34500
67000
69000
67000
67000
67000
67000
67000
67000
69000
69000
69000
69000
69000
67000
67000
69000
33000
33000
69000
67000
67000
69000
67000
67000
69000
67000
34500
34500
67000
69000
67000
69000
67000
69000
69000
67000
69000
69000
67000
67000
67000
69000X34500
34500
34500
33000
67000
67000
67000
34500
69000
67000
34500
69000X34500
34500
34500
66000
67000
69000
67000

x_voltage_rating
2400
7200
7200
7200
13090
7560X2520
7560X2520
2400
2400
4800X2400
7200X2400
7200X2400
4800X2400
7560X2520
4360
4360
13090
7200
7200
2520
33000
4160
34500
13090
2400
2400
2400
7200
7200
7200
4360X2520
2520
2520
2520
4360
13090
13090
4360
2520
2520
4360
4360
7560X4360
7560X4360
4360
7560X4360
13090
13090
4360
7200
7200
2400
2520
2520
4360
4360
13090X4360
4360
4160X2400
2520
7200
2520
4360
2400
4360
2520
4360
4360
13200
4360
7560X4360
2520
2400
2400
4160
2520
7200
7200
2520
2520
2520
2400
4360
4360
2520
13090
4360
480X240
6600X2200
2520
34500
7200

y_voltage_rating

2300
7200

2520

2520

2520
2520

2520

13200

Attachment to Response to AG-2 Question No. 102(b)
Page 1 of 2
Wolfe

 location
Lexington Substation Department
Lexington Substation Department
Lexington Substation Department
Lexington Substation Department
Lexington Substation Department
Lexington Substation Department
Lexington Substation Department
Lexington Substation Department
Lexington Substation Department
Lexington Substation Department
Lexington Substation Department
Lexington Substation Department
Lexington Substation Department
Lexington Substation Department
Lexington Substation Department
Lexington Substation Department
Lexington Substation Department
Lexington Substation Department
Lexington Substation Department
Lexington Substation Department
Lexington Substation Department
Toyota North
Imboden
Danville Substation Department
Danville Substation Department
Danville Substation Department
Danville Substation Department
Danville Substation Department
Danville Substation Department
Danville Substation Department
Danville Substation Department
Danville Substation Department
Danville Substation Department
Danville Substation Department
Danville Substation Department
Danville Substation Department
Kenton
Big Stone Gap Storeroom
Big Stone Gap Storeroom
Big Stone Gap Storeroom
Big Stone Gap Storeroom
Big Stone Gap Storeroom
Big Stone Gap Storeroom
Big Stone Gap Storeroom
Big Stone Gap Storeroom
Lebanon Junction
Midway Storeroom
Eastland Storage
Eastland Storage
Eastland Storage
Eastland Storage
Eastland Storage
Eastland Storage
Eastland Storage
Eastland Storage
Eastland Storage
Midway Storeroom
Pineville Substation Department

equip_category
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS
POWER TRANSFORMERS

equip_type
WithLTC
WithLTC
WithLTC
WithLTC
WithLTC
WithLTC
NonLTC
NonLTC
NonLTC
WithLTC
NonLTC
WithLTC
WithLTC
WithLTC
NonLTC
NonLTC
NonLTC
NonLTC
WithLTC
NonLTC
WithLTC
WithLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
WithLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
NonLTC
WithLTC
WithLTC
NonLTC
NonLTC
WithLTC
WithLTC
WithLTC
WithLTC
WithLTC
WithLTC
WithLTC
NonLTC
WithLTC

manufacturer
Pennsylvania
Waukesha
General Electric
General Electric
Mcgraw-Edison
General Electric
ABB
Howard Industries
Westinghouse
Jordan
Westinghouse
Howard Industries
General Electric
OTC Services
Howard Industries
General Electric
General Electric
General Electric
Kuhlman
General Electric
General Electric
Waukesha
Westinghouse
Howard Industries
Howard Industries
Howard Industries
Westinghouse
General Electric
General Electric
General Electric
General Electric
General Electric
Howard Industries
General Electric
General Electric
General Electric
General Electric
General Electric
Westinghouse
Westinghouse
Hevi Duty
General Electric
Hevi Duty
General Electric
General Electric
Waukesha
Delta Star
Pennsylvania
Westinghouse
General Electric
General Electric
Kuhlman
Howard Industries
General Electric
Westinghouse
OTC Services
Westinghouse
Pennsylvania

equip_no
TX000129
TX000056
O0177
B0432
C0463
B0404
C0529
KT0045
B0190
B0284
0949
KT0038
W0318
C0445
KT0046
B0271
W0031
W0030
S0019
B0244
W0308
S0012
T0226
TX000066
TX000065
TX000064
C0335
B0290
B0254
C0326
B0381
B0291
KT0001
B0172
C0370
C0174
B0339
O0235
O0217
O0216
O0194
O0162
O0195
O0237
O0236
S0072
P0003
TX000081
W0242
B0310
C0476
B0473
KT0032
B0247
C0407
C0443
P0002
TX000131

serial_no
C-09132-5-2
GT-01744
F960874
H881790
C-04792-5-1
H880250
SHB13901
308756-4410
5068922
E690221
6530700
260406-3610
G860320
PFP11793
296569-4210
C859779
8623674
8176206
282836-98-1
8627703
G860003B
A3417T
RBS-25221
3331704913
3331694913
3331684913
6533830
F10445264P
D430342
C500404
H888375
F10445364P
240102-1307
B500887
C859941C
8277752
F961661
8686823
79A370845
79A371760
GM239943
C503164
GM243473
8686825
8686824
A5869T
E78321295
R-08645-1-1
6994687
F960693
G860196C
252725-95-1
205279-2109
C859191
PBR97631
PFP11791
5067276
C-09132-5-4

operating_class
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution

owner
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU
KU

mfg_date
12/1/2015
10/30/2013
1/1/1967
1/1/1985
1/1/1974
1/1/1978
1/1/1995
12/1/2010
1/1/1953
3/1/2009
1/1/1954
12/1/2010
1/1/1975
12/1/2013
11/1/2010
1/1/1962
1/1/1948
1/1/1948
7/1/1999
1/1/1958
1/1/1971
3/10/1999
1/1/1982
12/1/2013
2/1/2014
2/1/2014
1/1/1955
1/1/1964
1/1/1959
1/1/1955
1/1/1974
1/1/1964
2/1/2007
1/1/1951
1/1/1962
1/1/1948
1/1/1969
1/1/1947
1/1/1979
1/1/1979
1/1/1977
1/1/1956
1/1/1977
1/1/1947
1/1/1947
8/1/2007
1/1/1996
8/1/2014
8/22/1963
1/1/1967
1/1/1975
1/1/1995
10/1/2009
1/1/1959
1/17/1981
12/1/2013
1/1/1953
4/1/2016

operation_center
Lexington Substation Departmen
Lexington Substation Departmen
Lexington Substation Departmen
Lexington Substation Departmen
Lexington Substation Departmen
Lexington Substation Departmen
Lexington Substation Departmen
Lexington Substation Departmen
Lexington Substation Departmen
Lexington Substation Departmen
Lexington Substation Departmen
Lexington Substation Departmen
Lexington Substation Departmen
Lexington Substation Departmen
Lexington Substation Departmen
Lexington Substation Departmen
Lexington Substation Departmen
Lexington Substation Departmen
Lexington Substation Departmen
Lexington Substation Departmen
Lexington Substation Departmen
Lexington
Norton
Danville
Danville
Danville
Danville
Danville
Danville
Danville
Danville
Danville
Danville
Danville
Danville
Danville
Maysville
Norton
Norton
Norton
Norton
Norton
Norton
Norton
Norton
Elizabethtown
Lexington
Lexington
Lexington
Lexington
Lexington
Lexington
Lexington
Lexington
Lexington
Lexington
Lexington
Pineville

substation_crew_site
LX
LX
LX
LX
LX
LX
LX
LX
LX
LX
LX
LX
LX
LX
LX
LX
LX
LX
LX
LX
LX
LX
OD
DV
DV
DV
DV
DV
DV
DV
DV
DV
DV
DV
DV
DV
LX
OD
OD
OD
OD
OD
OD
OD
OD
DV
LX
LX
LX
LX
LX
LX
LX
LX
LX
LX
LX
PN

position_operating_class
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution

h_voltage_rating
67000
138000X69000
69000X34500
67000
67000
138000
67000
67000
69000
67000
69000X34500
67000
69000X34500
67000
67000
67000
34500
34500
67000
69000
67000
138000
69000
34500
34500
34500
67000
34500
34500
69000X34500
67000
34500
67000
67000
67000
66000
138000
34500
22900
22900
22900
22900
22900
34500
34500
161000X67000
138000X69000
69000
67000
67000
67000
67000
67000
67000
67000
67000
69000X34500
67000

x_voltage_rating
13090
13090
13090
13090
13090
12470X8320
13090
13090
7200X14400
13090
12470X4160
4360
13090
13090
13090
4360
2400
2400
13090
2400
13090X4360
13200
34500X23000
2400
2400
2400
4360
480X240
480X240
12470X4160
13090
480X240
13090
4360X2520
2400
7200
13090X4360
2400
7200X2400
7200X2400
13090
4360
13090X4360
2400
2400
13090
13200
34500
13090
4360
13090
13800
13090
4360
4360X2520
13090
12470X4160
13090

y_voltage_rating

2400

12470

Attachment to Response to AG-2 Question No. 102(b)
Page 2 of 2
Wolfe

 equip_category
POWER TRANSFORMERS
POWER TRANSFORMERS

equip_type manufacturer equip_no serial_no
WithLTC Delta Star
P0003
E78321295
NonLTC Westinghouse P0002
5067276

operating_class
Distribution
Distribution

owner
KU
KU

alternate_name
Portable Substation
Portable Substation (B0184)

position_operatinpower_tranh_voltage_ratingx_voltage_rati base_rating
Distribution
Portable 138000X69000 13200
30
Distribution
Portable 69000X34500 12470X4160
7.5

Attachment to Response to AG-2 Question No. 102(c)
Page 1 of 1
Wolfe

 Equipment
Transformers

Type
Distribution

Make
All

Proposed
Activity Name
Quarterly
Inspection

Task
Bushing oil level inspection. Perform a visual inspection to check the oil level.
Perform functional test.
Perform visual inspection.

Monitor fan operation and listen for abnormal noise.
Check bushings for contamination and damaged insulation.

Perform visual inspection.

Perform a visual inspection of the transformer, LTC, bushings, gaskets, valves, piping and welds for oil leaks and
check oil levels.
Perform visual inspection of temperature indicators, and compare readings with other indicators at the station.
Record and trend results.
Check for obstructions and valve positions.

Perform visual inspection.
Perform visual inspection.

In service
Diagnostic
Maintenance

Record LTC counter
readings.
Perform visual inspection.

Check and record LTC counter reading.Record position indicator present position, high and low.

Record demand.
Perform visual inspection.

Record Load Demand Meter Readings
Inspect Primary Fuses

Perform visual inspection.

Check nitrogen system regulator

Perform Dissolved Gas
Analysis (LTC)

Sample oil in the LTC compartment for DGA and Mini-Screen. Send to system lab for analysis. Lab will record and
trend results. If results are above a specified limit or abnormal gas ratios, investigate and recondition as required.

Perform Dissolved Gas
Analysis (Main)

Sample oil in main tank for DGA and Mini-Screen. Send to system lab for analysis. Lab will record and trend results.
If results are above a specified limit or abnormal gas ratios, investigate and recondition as required.

Perform functional test.

Prove the operation of the LTC manual/automatic control loop and ensure regulatory voltage tolerances are
maintained.
See Infrared Inspection Plan and Guidelines. Check on temperature differential between main tank and LTC
compartment. Look for temperature inconsistencies in radiators.
Perform power factor test in conjunction with maintenance of associated transformer. Record and trend results for
age exploration. Review results with respect to determining the effectiveness of this test.
Perform watts loss Doble test in conjunction with transformer power factor tests. Record and trend results.

Perform infrared scan.
Out of Service
Diagnostic
Maintenance

LTC Overhaul

Task Description

Insulation Power Factor
Test
Perform insulation
resistance test.
Perform Excitation Test
Perform functional test.
Perform functional test.
Perform visual inspection.

Inspect control cabinet

Perform winding excitation test in conjunction with maintenance of associated transformer. Record and trend results
for age exploration. Review results with respect to determining the effectiveness of this test.
Perform a functional test of tap changer in conjunction with preventative maintenance of associated apparatus.
Listen for abnormal operation. Record and trend results.
Verify temperature alarms with cooling equipment operation, in conjunction with LTC maintenance.
Inspect current boxes for leaks or loose connections

Perform internal inspection. Inspect and adjust operating mechanism and assess condition of stationary and arcing contacts. Filter tap changer
oil. Inspect and clean load tap changer compartment.
Check fault pressure relay Check Fault Pressure Relay

Transformer
Maintenance

Check nitrogen system
Check nitrogen system regulator & alarms
Test fuses.
Perform air flow test on S&C Power fuses if applicable.
Perform internal inspection. Filter and condition oil. Visually inspect internal components and connections for abnormalities and tightness.

Attachment to Response to AG-2 Question No. 102(d)
Page 1 of 1
Wolfe

 Failure Date

Transformer

Manufacture Year

4/11/2012
5/30/2012
7/26/2012
10/18/2012
12/20/2012
2/6/2013
2/22/2013
7/31/2013
8/8/2013
5/5/2014
3/14/2015
4/2/2015
4/27/2015
5/14/2015
6/11/2015
7/27/2015
8/9/2015
10/13/2015
12/14/2015
8/26/2016
8/28/2016
10/22/2016
12/19/2016

KT0047
B0304
KT0035
C0448
C0445
C0443
W0106
B0307
T0206
B0319
B0404
B0183
O0182
KT0007
C517
B0288
B355
C0415
C0329
M0005
T0184
C0400
C0424

2011
1966
2010
1969
1969
1969
1951
2008
1954
1967
1978
1953
1971
2007
1994
1963
1971
1966
1955
1956
1972
1965
1967

Substation
Waco
Sardis
Carntown
Russell Springs
Shelbyville South
Harrodsburg East
Clay KU
Kentucky State Hospital
Pocket
Farmers
Midway
Carlisle
Boonesboro Park
McKee Road
Bardstown City
Bonnieville
American Avenue
Pine Hill
Bens Branch
Lynch
Andover
Etown 3
Munfordville

Cause of Failure
Voltage regulation
Proactive replacement
Proactive replacement
Failed due to internal fault
Voltage regulation
Proactive replacement
Failed due to internal fault
Failed due to internal fault
Failed due to internal fault
Failed due to internal fault
Bushing failure
Proactive replacement
Failed due to internal fault
Proactive replacement
Bushing failure
Failed due to internal fault
Bushing failure
Voltage regulation
Failed due to internal fault
Failed due to internal fault
Failed due to internal fault
Bushing failure
Failed due to internal fault

Subsequent Action
Removed supplier from approved bidders list
Replaced with an available spare
Removed supplier from approved bidders list
Replaced with an available spare
Replaced with an available spare
Replaced with an available spare
Replaced with an available spare
Replaced with an available spare
Replaced with an available spare
Replaced with an available spare
Replaced with an available spare
Replaced with an available spare
Replaced with an available spare
Replaced with an available spare
Replaced bushings with new
Replaced with an available spare
Replaced bushings with new
Replaced with an available spare
Replaced with an available spare
Replaced with an available spare
Replaced with an available spare
Replaced all bushings with new
Replaced with an available spare

Customers Affected
0
0
0
1553
0
0
815
883
108
687
2049
0
121
0
1
322
2386
0
1
552
2
3
5596

Length of Outage (in
minutes)
0
0
0
71
0
0
1274
27
57
63
105
0
107
0
391
56
124
0
914
823
102
1607
579

Attachment to Response to AG-2 Question No. 102(e)
Page 1 of 1
Wolfe

 Response to AG-2 Question No. 103
Page 1 of 3
Wolfe/Conroy/Malloy
KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 103
Responding Witness: John K. Wolfe / Robert M. Conroy / John P. Malloy
Q-103. Regarding the response to AG1 – 372, provide the following:
a. Does the company currently have a SCADA system for their distribution
system?
b. How many SCADA capable reclosers does the company currently have on
their distribution system?
c. What is the difference between the proposed DA initiative SCADA capable
reclosers and the ones currently installed on the distribution system?
d. Did the company receive a CPCN for installation of its current distribution
SCADA system or SCADA capable reclosers?
i. If not, why not?
e. Describe in detail at what level of deployment the company needs a CPCN to
install SCADA capable reclosers.
f. Describe in detail how the company will use the information from the AMS
system to determine where to install SCADA capable reclosers.
g. Describe in detail how the company will use the information from the
distribution vegetation management program to determine where to install
SCADA capable reclosers.
A-103.
a. No, the Company does not currently have a SCADA system for distribution
lines.
b. 215 SCADA capable reclosers are installed on the Kentucky Utilities
distribution system.

 Response to AG-2 Question No. 103
Page 2 of 3
Wolfe/Conroy/Malloy
c. The proposed DA initiative reclosers will have communications equipment
installed upon purchase. Existing SCADA capable reclosers will require field
installation of communications equipment to enable communication via
DSCADA with the DMS.
d. No. The Company does not believe a CPCN was necessary for any SCADA
or SCADA-capable reclosers deployed to date, which were all ordinary
extensions of existing systems in the usual course of business. See also the
response to part e. below, particularly the portion of the larger quote from the
Commission’s April 13, 2016 final order in Case No. 2012-00428 that states,
“Some of the investments in existing Smart Grid technology were made after
the utilities had obtained a CPCN, and some were not. The Commission has
not found any of the investments to be unreasonable.” 1
e. In accordance with recent Commission precedent, the Company believes it is
appropriate for a utility to seek a CPCN for any major deployment of SCADA,
distribution automation (“DA”), or other smart-grid technology. The
Commission articulated this standard less than a year ago in its final order in
Case No. 2012-00428 regarding CPCNs for smart-grid-related investments:
The Commission believes that the record in this case demonstrates
that the deployment of Smart Grid technology, whether in the form
of smart meters or DA, varies from utility to utility, as are the
reasons for the investment decisions that are made. Some of the
investments in existing Smart Grid technology were made after
the utilities had obtained a CPCN, and some were not. The
Commission has not found any of the investments to be
unreasonable.
While the Commission supports the intent of the EISA 2007 Smart
Grid Investment Standard, we will not require its adoption. The
Commission does not find it practical for each jurisdictional utility
to be required to obtain a CPCN for every Smart Grid or meter
investment decision. …
…
With regard to CPCNs, the Commission finds it appropriate for
jurisdictional electric utilities to obtain CPCNs for major AMR

1

In the Matter of: Consideration of the Implementation of Smart Grid and Smart Meter Technologies, Case
No. 2012-00428, Order at 10 (Apr. 13, 2016).

 Response to AG-2 Question No. 103
Page 3 of 3
Wolfe/Conroy/Malloy
or AMI meter investments and distribution grid investments for
DA, SCADA or volt/var resources. 2
f. The information gained from the AMS deployment will not be utilized in
locating DA equipment such as SCADA capable reclosers. SCADA capable
recloser locations will be optimized by leveraging historical data from the
Outage Management System (OMS) and customer locations from the
Geographic Information System (GIS).
g. The Company will not use the information from the distribution vegetation
management program to determine where to install SCADA capable
reclosers. See the response to part f.

2

Id. at 10-11.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 104
Responding Witness: John P. Malloy / John K. Wolfe
Q-104. Regarding the response to AG1 – 373, provide the following:
a. Since the AMS and DSCADA are two distinct systems, describe in detail how
information gained from AMS deployment will be used to locate DA
equipment such as SCADA capable reclosers.
b. Explain how AMS deployment and SCADA capable reclosers initiatives can
be done simultaneously while optimizing recloser locations.
c. Describe any needed improvements to distribution transformer maintenance,
inspections and diagnostic maintenance.
A-104.
a. The information gained from the AMS deployment will not be used to locate
DA equipment such as SCADA capable reclosers. See the response to
Question No. 103.f.
b. See the responses to part a. and Question No. 103.f.
c. No improvements to substation distribution transformer maintenance,
inspections, and diagnostic maintenance are identifiable concurrent with this
response. Maintenance methods are subject to continuous review and
reevaluation.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 105
Responding Witness: Robert M. Conroy / John K. Wolfe
Q-105. Regarding the response to AG 1–376, provide clarification with a detailed
description of the following:
a. Distribution SCADA investments over the past 5 years.
b. Distribution SCADA capable equipment installations over the past 5 years.
c. Distribution SCADA capable reclosers installed over the past 5 years.
d. Redundant distribution transformer installations over the past 5 years.
e. CPCN’s received for any of the above activities.
A-105.
a. No distribution line SCADA investments have taken place over the past 5
years. Four (4) distribution reclosers have been connected to the transmission
SCADA system (EMS).
b. Two hundred eighty seven (287) distribution SCADA capable devices have
been installed over the past 5 years. This includes SCADA capable reclosers
and capacitors.
c. One hundred sixty seven (167) distribution SCADA capable reclosers have
been installed over the past 5 years.
d. 2016 - Innovation Drive Substation base 20 MVA; 2016 - Lakeshore
Substation base 20 MVA.
e. No CPCNs were received for any of the above activities. The Company does
not believe a CPCN was necessary for any of the above activities; rather, they
were all ordinary extensions of existing systems in the usual course of
business.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 106
Responding Witness: Robert M. Conroy / John K. Wolfe
Q-106. Regarding the response to AG1 – 391, provide the following:
a. 5 year program costs if the distribution automation initiative were scaled back
to a pilot program.
b. Would this require a CPCN?
A-106.
a. The distribution automation (“DA”) program as planned includes the benefits
of a pilot program. In a pilot program, DMS and DSCADA implementation
along with recloser installations would take place during 2017 – 2019
consistent with the current plan. Recloser installations in the following years
can be scaled up or back depending on actual DA performance.
b. See the response to Question No. 103(e). Generally speaking, the Company
does not believe a pilot program for DA would require a CPCN.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 107
Responding Witness: Lonnie E. Bellar
Q-107. Regarding the response to KLC 1-8a, clarify attachment reference to $000 and
verify that miscellaneous expense is not $4,647,613,000 in 2018 plan.
A-107. The attachment to KLC 1-8a, was inadvertently mislabeled in $000’s and should
have been labeled in $’s, $4,647,613 is the correct amount for the change in
miscellaneous expense from 2018 to 2019. KU filed revised attachments to KLC
1-8a and KLC 1-8b on February 9, 2017.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 108
Responding Witness: William S. Seelye
Q-108. Regarding the response to AG1 – 291, provide the loss factors for all categories
over the past 10 years and describe the voltage levels for primary and secondary.
A-108. The Company does not determine loss factors annually. Therefore, the requested
loss factor information is not available. The loss factors used to develop the
allocation factors for the cost of service study were based on a Loss Study dated
August 2012. The primary voltages are 2400/4160Y volts, 7200/12,470Y volts,
or 34,500 volts. The secondary voltages include any available voltages below
these levels, including 120/240 volts three-wire and four-wire, 120/208Y volts
three-wire and four-wire, 240 volts three-wire, 480 volts three-wire, and
277/480Y volts four-wire service.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 109
Responding Witness: Lonnie E. Bellar
Q-109. Regarding the response to AG 1-361, provide the MW miles for each
transmission line listed in response to AG 1-361(c). Provide response in an excel
spreadsheet.
A-109. See attached.

 The attachment is being
provided in a separate
file in Excel format.

Response to AG-2 Question No. 110
Page 1 of 2
Bellar
KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 110
Responding Witness: Lonnie E. Bellar
Q-110. Regarding the response to AG 1-363, provide the following:
a. Explain why 2013 switch replacement costs were negative.
b. Explain why no expenditures were made in the 5-year period for underground
cable replacement.
c. Explain accelerated defective equipment replacement.
d. Explain high expenditures for circuit breaker replacement in 2012.
A-110.
a. The negative costs for 2013 reflect a reallocation of costs incorrectly assigned
to this category/asset class in a prior year.
b. While the Company did not have expenditures for underground cable
replacement, they did have expenditures for repairs on underground
accessories (terminations, splices, etc.). Repairs on underground accessories
are often a leading indicator that the underground cable system is nearing the
end of its useful life and is a driver for the proactive replacement program
proposed. The investments in underground cable replacement planned for the
next five years are on lines that have experienced failures and associated
underground accessory repairs.
c. The Company has increased defective equipment replacements in an effort to
reduce the backlog of defective equipment identified through inspection
programs.
d. The increased spend in 2012 under KBR-12 is due to addressing an identified
need to replace specific circuit breakers operating at 69kV– 161kV at various
locations. In addition, multiple 345kV breakers were replaced at the Ghent
switchyard as part of a multi-year project to replace nine circuit breakers. The
breaker replacements at Ghent were initiated as a result of issues experienced
with these breakers in 2009, in which two breakers failed, and due to the

 Response to AG-2 Question No. 110
Page 2 of 2
Bellar
criticality of these components to the Ghent power plant and the bulk electric
system.

 Response to AG-2 Question No. 111
Page 1 of 3
Bellar
KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 111
Responding Witness: Lonnie E. Bellar
Q-111. Regarding the response to AG1 – 378, provide the following:
a. Why project 151744 costs more than project 151811.
b. All costs involved in an auto switch installation such as the projects listed
above.
c. Why a 69 kV switch installation (project 147482 for example) is estimated to
cost more than an auto switch installation (project 151811 for example).
d. All costs involved in a switch replacement.
e. Why project 144364 costs more than project 144632.
f. All costs involved in a breaker installation such as the projects listed above.
g. All costs involved in project 151794.
h. All costs involved in project 147565.
i. All costs involved in projects 147592, 147593, and 147594.
A-111.
a. Project 151744 is an Auto installation on a transmission pole while project
151811 is located in a substation. The primary difference in cost is due to
materials and contract labor associated with the installation of the
transmission pole in project 151744.
b. Costs for the construction of auto switches can vary by location. For a
transmission structure installation, the major components are a structure,
switch, motor, communications, PTs, and associated relaying. Some of the
proposed locations have an existing structure and switch and would only
require motor, communications, PTs and associated relaying. Other
installations are in a substation and would not require the transmission

 Response to AG-2 Question No. 111
Page 2 of 3
Bellar
structure. Final testing and commissioning is required to place the equipment
in service.
c. Project 147482 requires the installation of a new transmission structure to
accommodate the motor operated switch which adds significantly to the cost.
Project 151811 already has switches installed in the substation steel and only
needs the addition of motors and the equipment for automating the switch.
d. A typical switch replacement will include the cost for removal of the existing
switch and, if needed, construction of a new transmission structure and the
purchase and installation of the switch itself and attachment to line conductors
followed by testing and commissioning.
e. Project 144364 involved the purchase and installation of 2 circuit breakers
into an existing substation and the purchase and installation of a new control
house to hold the associated relaying. This project also included the
construction of 2 substation bays to accommodate the breakers and
construction of a transfer bus to accommodate maintenance activity. Project
144632 involves the purchase and installation of a single breaker in an open
substation bay and the purchase and installation of a transclosure (a box to
accommodate the necessary relaying).
f. Breaker installations typically include the purchase of a single breaker, the
construction of a substation bay to place the breaker, associated line relaying,
and communications equipment and testing and commissioning.
g. See the table below.
h. See the table below.
i. See the table below.

 Response to AG-2 Question No. 111
Page 3 of 3
Bellar

Project
144364
144632
147482
147565
147592
147593
147594
151744
151794
151811

Bud Description
REL-Parkers Mill 604 Brkr
Adds
REL-Cawood 604 Brkr
Addition
REL Campbellsburg Switch
REL Haley MOS
REL Motor Op Switches KU
2019
REL Motor Op Switches KU
2020
REL Motor Op Switches KU
2021
REL-Campbellsville 605
Switch
REL Elizabethtown Tap
MOS
REL-Rockwell Motor-Auto

Company
and
Contract
Labor

Materials

Overheads,
Contingency
and Other

Total

$890,730

$731,539

$359,132 $1,981,401

$455,287
$217,250
$255,120

$251,452
$94,000
$170,080

$143,262
$29,569
$24,800

$1,001,500

$400,000

$105,112 $1,506,612

$1,215,000

$400,000

$153,425 $1,768,425

$1,256,000

$400,000

$140,760 $1,796,760

$118,580

$81,680

$43,365

$243,625

$293,500
$97,385

$185,000
$67,081

$107,121
$35,534

$585,621
$200,000

$850,001
$340,819
$450,000

 Response to AG-2 Question No. 112
Page 1 of 2
Bellar
KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 112
Responding Witness: Lonnie E. Bellar
Q-112. Regarding the response to AG1 – 409, provide the following:
a. When does LKE expect to perform an updated RTO membership analysis?
b. Did the 2012 analysis consider revenue from the PJM capacity market value?
If not why?
c. Reserve margin requirements if LKE joined either PJM or MISO.
d. Any changes to assumptions regarding cost allocation of regional PJM or
MISO projects since 2012.
e. Current present value benefits of reduction in spinning reserve.
f. Current estimate of third party transmission revenue to LKE with PJM or
MISO membership.
g. Current reduction of cost for elimination of ITO and RC less increased staff
costs for joining an RTO.
h. Reduction of depancaking costs if LKE joined an RTO.
i. Avoided long-term firm PTP transmission charges from joining an RTO.
j. Current forecast of 10-year capacity market revenue from sales in either PJM
or MISO.
k. Current adjusted projection cost savings from joining MISO for the next 10
years.
l. Current adjusted projection cost savings from joining PJM for the next 10
years.

 Response to AG-2 Question No. 112
Page 2 of 2
Bellar
A-112.
a. At this time, the Company has not made definitive plans to perform a new
cost/benefit study of becoming an RTO member.
b. Yes; however, since revenue received from the PJM capacity market is also
paid for by customers, the overall net difference in revenues and cost
associated with the PJM capacity market was not considered to have a
material impact on the results. The analysis assumed that if the Company
joined an RTO it would not change its targeted generation planning reserve
margin.
c. The analysis assumed that if the Company joined an RTO, it would not change
its targeted generation planning reserve margin.
d. The Company has not reevaluated any assumptions regarding cost allocation
of RTO regional projects since the 2012 analysis.
e. The Company has not reevaluated spinning reserve requirements of joining
an RTO since the 2012 analysis.
f. The Company has not reevaluated third party transmission revenue impacts
from joining an RTO since the 2012 analysis.
g. The Company has not reevaluated the net impact of eliminating ITO and RC
costs less increased staff costs from joining an RTO since the 2012 analysis.
h. See the response to AG 1-409.
i. See the response to AG 1-409.
j. The Company has not performed a current 10 year capacity market revenue
forecast for sales into PJM or MISO.
k. The Company has not reevaluated the financial impacts of joining MISO
since the 2012 analysis, which indicated an incremental present value cost of
$216.5 million.
l. The Company has not reevaluated the financial impacts of joining PJM since
the 2012 analysis, which indicated an incremental present value cost of $103
million.

 Response to AG-2 Question No. 113
Page 1 of 2
Conroy
KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 113
Responding Witness: Robert M. Conroy
Q-113. Has the Company ever considered requesting Commission approval for tariffs
regarding any of the following: (i) “Seasonal;” (ii) “Seasonal Agriculture;” and/or
(iii) “Agriculture”?
a. If not, why not?
b. If so, why does the Company not have such a tariff now?
A-113.
a. No, the Company has not requested Commission approval for tariffs
regarding the specific items noted. The Company has developed rates that
more closely reflect the cost of providing service. It is important for the
Company to design its rates so that the actual cost of providing service is
recovered through rates even when customers reduce their energy
consumption but still require the same utility infrastructure to serve them. A
utility must install distribution, transmission, and generation facilities to serve
a customer’s demand. Just because a customer’s demand is not always at the
maximum level does not mean that the fixed costs of the facilities installed to
meet the customer’s maximum demand will disappear. The fixed costs of the
facilities installed to meet a customer’s maximum demand will be incurred
even when the customer has a lower demand. In the case of localized
facilities, such as primary and secondary distribution lines, transformers,
substations, and transmission facilities, the utility must install sufficient
capacity to meet the customer’s maximum demand, whenever the demand
occurs. Therefore, a utility’s transmission and distribution fixed costs are
correlated to the customers’ maximum demands, not their average monthly
demands. Generation fixed costs are correlated to customer demands at the
time of the system peak. For most but not all customers, the customer’s
maximum demands occur near the
system peak. For system peak
demands, which drive the cost of generation fixed assets, customer load
diversity has an effect on the generation requirements that individual
customer demands place on the system.

 Response to AG-2 Question No. 113
Page 2 of 2
Conroy
In addition, when one rate class subsidizes another rate class it is referred to
as “inter-class subsidies”, but when customers within a particular rate class
subsidize other customers served under the same rate schedule it is referred
to as “intra-class subsidies.” The rate-making principle that should be
followed to avoid intra-class subsidies is that, as much as possible, fixed costs
should be recovered through fixed charges (such as the basic service charge
and demand charge) and variable costs should be recovered through variable
charges (such as the energy charge). If fixed costs are recovered through
variable charges, each kWh contains a component of fixed costs and
customers using more energy than the average customer in the class are
paying more than their fair share of fixed costs and margins, while customers
using less energy than the average customer in the class are paying less than
their fair share of fixed costs and margins. These fixed costs and margins
should be collected through the billing units associated with the appropriate
cost driver, and energy usage clearly is not the correct cost driver for fixed
costs. The collection of fixed costs through the energy charge typically results
in customers with above-average usage subsidizing customers with belowaverage usage. The collection of variable costs through fixed charges also
results in an intra-class subsidy, with customers with below-average usage
subsidizing customers with above-average usage. In order to eliminate this
source of intra-class subsidies, the Company wants to pursue a rate design
that moves more in the direction of recovering fixed costs through fixed
charges and variable costs through variable charges.
b. Not applicable.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 114
Responding Witness: Robert M. Conroy
Q-114. Has the Company performed any studies, analyses or research regarding the need
for or adoption of tariffs regarding any one of the three subject matters referenced
immediately above, or any combination thereof?
a. If not, why not?
b. If so, provide all studies, analyses, or research the Company has performed
regarding the aforementioned tariffs?
A-114.
a. No the Company has not performed any studies, analyses, or research
regarding the matters referenced in Question No. 113. See response to
Question No. 113(a).
b. Not applicable.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 115
Responding Witness: Robert M. Conroy
Q-115. Has the Company ever considered requesting Commission approval for a tariff
specific to sports-related facilities and/or sports fields owned by municipalities or
schools?
a. If not, why not?
b. If so, why does the Company not have such a tariff now?
A-115.
a. See the response to Question No. 113(a).
b. Not applicable.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 116
Responding Witness: Robert M. Conroy
Q-116. Has the Company performed any studies, analyses or research regarding the need
for or adoption of a tariff related to sports-related facilities and/or sports fields?
a. If not, why not?
b. If so, provide all studies, analyses, or research the Company has performed
regarding tariffs for the aforementioned subjects?
A-116.
a. No the Company has not performed any studies, analyses, or research
regarding the matters referenced. See the response to Question No. 113(a).
b. Not applicable.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 117
Responding Witness: Robert M. Conroy / John P. Malloy
Q-117. Has the Company ever engaged in any meetings, correspondence or
conversations with individuals or organizations regarding tariffs for: (i)
“Seasonal;” (ii) “Seasonal Agriculture;” (iii) “Agriculture,” and/or sports-related
facilities and/or sports fields?
a. If so, what has been the outcome of these engagements?
A-117. Yes.
a. The Company has engaged in conversations with various customers related
to possible tariff design for “Seasonal”, “Seasonal Agriculture”,
“Agriculture”, and/or sports-related facilities and/or sports fields. However,
those conversations have not yielded cost of service reasons to support the
development of those tariffs. The Company is always willing to discuss tariff
designs with its customers.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 118
Responding Witness: John P. Malloy
Q-118. Refer to the Company’s response to PSC 2-109. Explain why the Company
waited until April 2016 to change the tariff for the Greater Muhlenberg Parks and
Recreation System even though the system’s usage would have necessitated an
earlier move to Power Service.
A-118. In November 2015, the Company informed the Greater Muhlenberg Parks and
Recreation Department that the energy demand was averaging over 50 kW which
would require a rate change from General Service to Power Service. Since the
rate change would result in higher bills, the Greater Muhlenberg Parks and
Recreation Department requested time to explore options to reduce their demand.
The Company, consistent with filed and approved Terms and Conditions on Tariff
Sheet 101.1 - Customer Rate Assignment, did not change the rate until April 2016
since November through March was the Sporting Complex’s off season and
would not be in use. When Greater Muhlenberg Parks and Recreation could not
find a feasible option to lower their demand, the rate was changed in April 2016
in accordance with our tariffs.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 119
Responding Witness: Robert M. Conroy
Q-119. Refer to the Company’s response to PSC 2-109 and PSC 2-110. When did the
Power Service tariff change so that customers whose demand averages more than
50 KW are defaulted to that rate? This answer should include the date of the tariff
change and the case number in which the change was proposed and approved.
A-119. On February 5, 2009, the Commission entered an Order approving the unanimous
Settlement, Stipulation and Recommendation reached between KU and all
intervenors in its 2008 base rate case (Case No. 2008-00251). As part of said
Order, the Commission approved KU’s proposal to combine its then-existing
Large Power Rate LP with Mining Power Rate MP, and rename it Power Service
Rate PS. Effective February 6, 2009, the availability of service for secondary and
primary customers under Rate PS was limited to customers having minimum
average secondary loads of 50 kW and maximum average loads of 250 kW. The
50 kW minimum for secondary service has not been modified since its original
effective date. Customers with maximum average loads below 50 kW are
provided secondary service under Rate GS.

 KENTUCKY UTILITIES COMPANY
CASE NO. 2016-00370
Response to the Attorney General’s Supplemental Data Requests
Dated February 7, 2017
Question No. 120
Responding Witness: John P. Malloy
Q-120. Refer to the Company’s response to PSC 2-110. Subject to the customer’s
approval, provide the customer’s usage for each month since January 2010, in a
chart similar to the Company’s response to PSC 2-109.
A-120. See attached.

 Attachment to Response to AG-2 Question No. 120
Page 1 of 3
Malloy

Fredonia Food & More
Monthly Customer Usage - January 2010 to February 2017

Rate Category/Tariff
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary

Billing
Period
2010/01
2010/02
2010/03
2010/04
2010/05
2010/06
2010/07
2010/08
2010/09
2010/10
2010/11
2010/12
2011/01
2011/02
2011/03
2011/04
2011/05
2011/06
2011/07
2011/08
2011/09
2011/10
2011/11
2011/12
2012/01
2012/02
2012/03
2012/04
2012/05
2012/06
2012/07
2012/08
2012/09
2012/10
2012/11
2012/12
2013/01
2013/02
2013/03
2013/04

$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$

Revenue
Amount

Total
Energy

Demand
Billed

Demand
Measured

$

KWH

KW

KW

1,365.12
1,523.47
1,056.16
1,412.14
1,896.32
1,680.83
1,713.92
1,907.68
1,973.12
1,533.63
1,455.97
1,452.13
1,379.30
1,344.37
1,367.44
1,390.08
1,522.33
1,721.43
1,716.45
1,759.33
1,900.48
1,503.25
1,369.06
1,322.80
1,387.27
1,320.07
1,355.04
1,429.05
1,640.18
1,696.15
1,988.45
1,816.03
1,785.96
1,545.74
1,433.20
1,368.54
1,430.82
1,414.04
1,315.83
1,459.68

22,680
23,480
11,320
27,120
23,120
29,680
28,920
28,200
30,480
24,920
21,640
23,640
21,400
18,760
21,280
21,040
22,480
26,560
26,840
28,240
30,600
24,120
20,400
21,200
21,560
19,920
19,640
21,280
24,160
25,280
30,800
27,680
28,240
24,840
20,920
20,120
22,000
19,560
19,440
20,040

49.2
49.2
49.2
49.2
104.8
50.1
52.8
53.2
52.4
52.4
52.4
52.4
52.4
52.4
52.4
52.4
50.0
51.7
50.0
51.5
51.9
50.0
50.0
50.0
50.0
50.0
50.0
50.0
50.0
50.0
51.2
53.2
50.0
50.0
50.0
50.0
50.0
50.0
50.0
50.0

49.2
49.2
49.2
49.2
104.8
50.1
52.8
53.2
52.0
50.2
47.0
41.8
38.4
39.2
38.4
42.1
46.9
51.7
49.2
51.5
51.9
48.8
46.4
38.8
37.0
38.4
39.6
45.7
46.4
48.8
51.2
53.2
49.4
48.9
42.4
39.1
40.0
38.7
37.5
41.0

 Attachment to Response to AG-2 Question No. 120
Page 2 of 3
Malloy

Rate Category/Tariff
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
PS Secondary
GS Three Phase
GS Three Phase
GS Three Phase
GS Three Phase
GS Three Phase
GS Three Phase
GS Three Phase
GS Three Phase
GS Three Phase
GS Three Phase
GS Three Phase
GS Three Phase
GS Three Phase
GS Three Phase
GS Three Phase
GS Three Phase
GS Three Phase
GS Three Phase
GS Three Phase

Billing
Period
2013/05
2013/06
2013/07
2013/08
2013/09
2013/10
2013/11
2013/12
2014/01
2014/02
2014/03
2014/04
2014/05
2014/06
2014/07
2014/08
2014/09
2014/10
2014/11
2014/12
2015/01
2015/02
2015/03
2015/04
2015/05
2015/06
2015/07
2015/08
2015/09
2015/10
2015/11
2015/12
2016/01
2016/02
2016/03
2016/04
2016/05
2016/06
2016/07
2016/08
2016/09
2016/10

$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$

Revenue
Amount

Total
Energy

Demand
Billed

Demand
Measured

$

KWH

KW

KW

1,756.59
1,911.15
2,031.30
1,852.21
1,867.34
1,734.35
1,479.88
1,462.59
1,585.12
1,556.23
1,571.39
1,526.68
1,780.47
2,078.10
2,017.58
1,773.14
2,017.18
1,611.46
1,566.66
1,526.33
1,541.16
1,571.41
1,515.23
1,877.30
2,019.37
2,566.88
2,614.05
2,695.50
2,892.65
2,247.23
2,040.00
2,102.73
2,110.88
1,885.44
2,063.01
1,946.33
2,310.43
2,311.32
2,609.52
2,996.80
2,528.46
2,177.59

24,400
27,000
29,520
27,160
27,640
27,760
20,680
20,920
22,600
20,600
20,200
19,360
21,840
27,800
27,800
23,720
29,800
21,800
20,960
21,000
19,280
19,880
19,080
18,600
20,280
25,200
25,600
25,800
27,920
21,400
19,560
20,640
20,440
17,240
18,280
18,440
22,200
21,880
24,880
28,080
23,560
20,600

50.0
50.0
50.0
50.2
50.3
50.0
50.0
50.0
50.0
50.0
50.0
50.0
50.0
50.0
50.0
50.0
50.0
50.0
50.0
50.0
50.0
50.0
50.0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0

45.3
48.9
50.0
50.2
50.3
48.9
41.1
41.1
38.6
39.0
38.6
38.4
43.8
46.6
48.0
47.0
46.3
45.3
40.3
40.0
37.7
37.1
37.5
40.1
43.3
44.3
45.0
49.2
48.6
43.1
39.8
38.1
39.6
38.6
38.6
42.5
41.0
41.6
45.3
45.0
45.5
41.9

 Attachment to Response to AG-2 Question No. 120
Page 3 of 3
Malloy

Rate Category/Tariff
GS Three Phase
GS Three Phase
GS Three Phase
GS Three Phase

Billing
Period
2016/11
2016/12
2017/01
2017/02

$
$
$
$

Revenue
Amount

Total
Energy

Demand
Billed

Demand
Measured

$

KWH

KW

KW

2,225.51
1,887.13
1,916.23
1,775.88

21,200
17,720
18,200
16,400

0
0
0
0

43.8
38.5
35.6
36.6