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DIRECT TESTIMONY OF ELIZABETH A. BLANKENSHIP
On Behalf of Arizona Public Service Company
Docket No. E-01345A-19-0236
October 31, 2019
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Table of Contents
I. INTRODUCTION .................................................................................................... 1
II. SUMMARY ............................................................................................................. 2
III. HISTORICAL AND TEST YEAR ACCOUNTING DATA .................................. 5
A. Summary Schedules ......................................................................................... 6
B. Rate Base Schedules ........................................................................................ 7
C. Test Year Income Statements ........................................................................ 11
D. Cost of Capital ............................................................................................... 12
E. Financial Statements and Statistical Schedules ............................................. 14
F. Projections and Forecasts ............................................................................... 15
IV. PRO FORMA ADJUSTMENTS TO TEST YEAR ............................................... 16
A. Types of Pro Forma Adjustments .................................................................. 16
B. Pro Forma Adjustment Descriptions .............................................................. 17
1. Remove Test Year Surcharge Revenue and Expense ........................... 17
2. Include West Phoenix Unit 4 Regulatory Disallowance ....................... 17
3. Include Interest Expense on Customer Deposits ................................... 18
4. Adjust Depreciation Expense – 2019 Depreciation Rate Study .......... 19
5. Adjust for Post-Test Year Plant Additions ............................................. 20
6. Adjust Decommissioning Costs ............................................................... 21
7. Annualize Payroll Expense ....................................................................... 24
8. Normalize Employee Benefits ................................................................. 25
9. Remove Supplemental Excess Benefit Retirement Plan Expense ....... 26
10. Remove Stock Compensation .................................................................. 26
11. Include Active Union Medical Trust ....................................................... 26
12. Normalize Cash Incentive ......................................................................... 27
13. Normalize Income Tax Expense/Interest Synchronization .................. 27
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14. Annualize Property Tax Expense............................................................. 27
15. Include Property Tax Deferral .................................................................. 28
16. Annualize Four Corners Coal Reclamation Costs ................................. 29
17. Annualize Navajo Coal Reclamation Costs ............................................ 30
18. Adjust Cash Working Capital for Cost of Service ................................. 31
19. Normalize Fossil and Nuclear Maintenance Expenses ......................... 32
20. Adjust Sundance Maintenance Expense Accrual .................................. 33
21. Remove Navajo Power Plant Costs ......................................................... 34
22. Include Ocotillo Modernization Project Deferral .................................. 34
23. Include Four Corners Selective Catalytic Reduction Deferral ............. 35
24. Include Cholla Inventory .......................................................................... 37
25. Include Four Corners Inventory ............................................................... 37
26. Normalize Advertising Expense .............................................................. 37
27. Include Removal Costs Associated with West Phoenix ....................... 38
28. Include Fire Mitigation Costs ................................................................... 38
29. Include Customer Affordability Benefits ............................................... 38
30. Remove Out of Period and Miscellaneous Items ................................... 39
31. Include Cloud Computing Deferral ......................................................... 39
32. Include Amortization of Excess Deferred Tax (TEAM III) ................. 40
33. Adjust Cholla Unit 2 Regulatory Asset Amortization .......................... 41
V. REQUEST FOR PROPERTY TAX DEFERRAL ................................................. 41
VI. CONCLUSION ...................................................................................................... 42
ATTACHMENT LIST
Remove Test Year Surcharge Revenue and Expense ........................ Attachment EAB-1DR
Include West Phoenix Unit 4 Regulatory Disallowance (Rate Base) .......................................................... Attachment EAB-2DR
Include West Phoenix Unit 4 Regulatory Disallowance (Income Statement) ......................................... Attachment EAB-3DR
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Include Interest Expense on Customer Deposits .............................. Attachment EAB-4DR
Adjust Depreciation Expense – 2019 Depreciation Rate Study ..... Attachment EAB-5DR
Adjust for Post-Test Year Plant Additions (Rate Base) ................... Attachment EAB-6DR
Adjust for Post-Test Year Plant Additions (Income Statement) ....... Attachment EAB-7DR
Annualize Payroll Expense. ................................................................... Attachment EAB-8DR
Normalize Employee Benefits .............................................................. Attachment EAB-9DR
Remove Supplemental Excess Benefit Retirement Plan Expense ......... Attachment EAB-10DR
Remove Stock Compensation ................................................................. Attachment EAB-11DR
Include Active Union Medical Trust. .................................................. Attachment EAB-12DR
Normalize Cash Incentive. ................................................................... Attachment EAB-13DR
Normalize Income Tax Expense/Interest Synchronization. ............ Attachment EAB-14DR
Annualize Property Tax Expense. ...................................................... Attachment EAB-15DR
Include Property Tax Deferral (Rate Base) .................................. Attachment EAB-16DR
Include Property Tax Deferral Amortization (Income Statement) .......... Attachment EAB-17DR
Annualize Four Corners Coal Reclamation Costs ........................ Attachment EAB-18DR
Annualize Navajo Coal Reclamation Costs. ................................. Attachment EAB-19DR
Adjust Cash Working Capital for Cost of Service (Rate Base) .......Attachment EAB-20R
Adjust Cash Working Capital for Cost of Service (Income Statement) ............................................................ Attachment EAB-21DR
Normalize Nuclear Maintenance Expense ......................................... Attachment EAB-22DR
Normalize Fossil Maintenance Expense ............................................ Attachment EAB-23DR
Adjust Sundance Maintenance Expense Accrual ............................. Attachment EAB-24DR
Remove Navajo Power Plant Costs ..................................................... Attachment EAB-25DR
Include Ocotillo Modernization Project Deferral .............................. Attachment EAB-26DR
Amortize Ocotillo Modernization Project Deferral ........................... Attachment EAB-27DR
Include Ocotillo Maintenance Expense................................................... Attachment EAB-28DR
Include Four Corners Selective Catalytic Reduction Deferral. ............... Attachment EAB-29DR
Amortize Four Corners Selective Catalytic Reduction Deferral. ............ Attachment EAB-30DR
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Include Cholla Inventory ..................................................................... Attachment EAB-31DR
Include Four Corners Inventory .......................................................... Attachment EAB-32DR
Normalize Advertising Expense ......................................................... Attachment EAB-33DR
Include Removal Costs Associated with West Phoenix .................. Attachment EAB-34DR
Include Fire Mitigation Costs .............................................................. Attachment EAB-35DR
Include Customer Affordability Benefits .......................................... Attachment EAB-36DR
Remove Out of Period and Miscellaneous Items .............................. Attachment EAB-37DR
Include Cloud Computing Deferral .................................................... Attachment EAB-38DR
Include Amortization of Excess Deferred Tax (TEAM III) ............ Attachment EAB-39DR
Adjust Cholla Unit 2 Regulatory Asset Amortization ..................... Attachment EAB-40DR
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DIRECT TESTIMONY OF ELIZABETH A. BLANKENSHIP ON BEHALF OF ARIZONA PUBLIC SERVICE COMPANY
(Docket No. E-01345A-19-0236)
I. INTRODUCTION
Q. PLEASE STATE YOUR NAME, OCCUPATION AND BUSINESS
ADDRESS.
A. My name is Elizabeth A. Blankenship. I am the Vice President, Controller and
Chief Accounting Officer for Arizona Public Service Company (APS or
Company), a subsidiary of Pinnacle West Capital Corporation (Pinnacle West). I
am primarily responsible for overseeing the financial accounting and reporting
functions of the Company and Pinnacle West. My business address is 400 N. 5th
Street, Phoenix, Arizona 85004.
Q. WHAT IS YOUR EDUCATIONAL AND PROFESSIONAL
BACKGROUND?
A. I received a Bachelor of Science degree in Business with a major in Accounting
from Arkansas State University in 1993. From 1993 to 2000, I was employed as
an accountant for two companies in the long-term healthcare service industry. I
joined APS in October 2000 as a Senior Accountant and spent the past 19 years
working for APS in the Financial Reporting Department, Accounting Operations
Department, and the Revenue/Regulatory Accounting Department.
Prior to my current position as the Vice President, Controller and Chief Accounting
Officer, I was responsible for overseeing the accounting functions of the
generation, transmission, distribution, customer service, and corporate resource
areas, as well as the accounting systems and budget governance functions at
Pinnacle West and APS as the Director of Accounting Operations. Prior to that
position I was responsible for the revenue and regulatory accounting, asset
accounting, accounts receivable, and cash control functions at APS as the Manager
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of the Revenue/Regulatory Accounting Department. I am a Certified Public
Accountant, a member of the Arizona Society of Certified Public Accountants and
a member of the Edison Electric Institute’s Property Accounting Committee.
II. SUMMARY
Q. PLEASE SUMMARIZE YOUR TESTIMONY.
A. My testimony addresses the historical and forecasted accounting information and
pro forma adjustments required by the Standard Filing Requirements (SFR) of the
Arizona Corporation Commission (ACC or Commission) in support of the
Company’s rate case filing. I sponsor historical information for the 12-month
period ended June 30, 2019 (Test Year), which was used as the Test Year in this
proceeding, as well as any prior years presented as part of the SFR Schedules. I
also sponsor the projected information contained in these schedules:
A-2 through A-5 – Summary Schedules
B-1, B-3 through B-5 – Rate Base Schedules
C-1 – Test Year Income Statements
C-3 – Computation of Gross Revenue Conversion Factor
D-1 through D-4 – Cost of Capital
E-1 through E-9 – Financial Statements and Statistical Schedules
F-1 through F-4 – Projections and Forecasts
APS witness Leland R. Snook jurisdictionalizes the Total Company data to
separate those items that fall within the Commission’s regulatory jurisdiction from
those that do not.
I will also provide direct testimony on certain pro forma adjustments made to the
Test Year on SFR Schedules B-2 and C-2. Specifically, I will be sponsoring the
“Total Company” column for the following pro formas on SFR Schedule B-2:
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The Post-Test Year Plant Addition Pro Formas
Include West Phoenix Unit 4 Regulatory Disallowance
Include Property Tax Deferral
Adjust Cash Working Capital for Cost of Service
Include Ocotillo Modernization Project Deferral
Include Four Corners Selective Catalytic Reduction Deferral
Include Cloud Computing Deferral
Include Amortization of Excess Deferred Tax (TEAM III)
Additionally, I will be sponsoring the “Total Company” columns for the following
pro formas on SFR Schedule C-2:
Remove Test Year Surcharge Revenue and Expense
Include West Phoenix Unit 4 Regulatory Disallowance
Include Interest Expense on Customer Deposits
Adjust Depreciation Expense – 2019 Depreciation Rate Study
Adjust for Post-Test Year Plant Additions
Annualize Payroll Expense
Normalize Employee Benefits
Remove Supplemental Excess Benefit Retirement Plan Expense (SERP)
Remove Stock Compensation
Include Active Union Medical Trust
Normalize Cash Incentive
Normalize Income Tax Expense/Interest Synchronization
Annualize Property Tax Expense
Include Property Tax Deferral Amortization
Annualize Four Corners Coal Reclamation Costs
Annualize Navajo Coal Reclamation Costs
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Adjust Cash Working Capital for Cost of Service
Normalize Nuclear Maintenance Expense
Normalize Fossil Maintenance Expense
Adjust Sundance Maintenance Expense Accrual
Remove Navajo Power Plant Costs
Amortize Ocotillo Modernization Project Deferral
Include Ocotillo Maintenance Expense
Amortize Four Corners Selective Catalytic Reduction Deferral
Include Cholla Inventory
Include Four Corners Inventory
Normalize Advertising Expense
Include Removal Costs Associated with West Phoenix
Include Fire Mitigation Costs
Include Customer Affordability Benefits
Remove Out of Period and Miscellaneous Items
Adjust Cholla Unit 2 Regulatory Asset Amortization
These adjustments are consistent with prior filings and represent “normalizations”
and “annualizations” as discussed later in my testimony. These operating income
pro formas are tax-affected, that is they include an income tax calculation at the
adjusted Test Year federal and state statutory income tax rates, expected to be in
place when new retail rates go into effect. The SFR Schedule C-2 pro formas that
have a related Rate Base pro forma also include a calculation for synchronization
of interest expense, which in turn is used in determining overall jurisdictional
federal and state income tax expense.
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I will discuss and explain the “Gross Revenue Conversion Factor” that is used to
gross-up operating income to account for income taxes, as presented on SFR
Schedule C-3. In addition, I will present testimony concerning the capital structure
of the Company and provide APS’s actual overall cost of capital, as presented on
SFR Schedules D-1 through D-4. This discussion will include information on the
cost of equity provided by APS witness Ann E. Bulkley, APS’s return on equity
(ROE) witness, as well as the Company’s embedded cost of debt. In addition, I
will sponsor the various schedules relating to the Company’s financial statements
on SFR Schedules E-1 through E-9. SFR Schedule E-6 refers only to
“combination” utilities (e.g., electric and gas) and thus is not applicable to APS.
Finally, I will sponsor the data on SFR Schedules F-1 through F-4. These
schedules also include projected income statements and projected changes in
financial position.
III. HISTORICAL AND TEST YEAR ACCOUNTING DATA
Q. PLEASE DESCRIBE THE ACCOUNTING INFORMATION CONTAINED
WITHIN THE SFR SCHEDULES THAT YOU ARE SPONSORING.
A. My testimony covers historical accounting data, including the actual data for the
Test Year. The majority of this information is disclosed directly or indirectly in
both the consolidated APS and consolidated Pinnacle West audited and reviewed
financial statements, which are included in filings made with the Securities and
Exchange Commission (SEC) and the Federal Energy Regulatory Commission
(FERC) for the relevant periods.
Additionally, all of the accounting information provided in my testimony complies
with Generally Accepted Accounting Principles (GAAP), which is required by the
SEC for publicly-traded companies. These are the principles that accounting
professionals use to prepare public financial statements. One major goal of GAAP
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is to make financial statements comparable from period to period, from firm to
firm, and from industry to industry. It also provides consistency from jurisdiction
to jurisdiction. In addition to GAAP, APS’s accounting practices comply with
other applicable utility accounting standards, such as the FERC Uniform System
of Accounts, which this Commission has adopted for electric and gas utilities.1 My
testimony also covers the forecasted accounting statements and financial results,
which is periodically supplied to investors and filed with the SEC. All of the
accounting projections provided in my testimony follow GAAP and comply with
other applicable utility accounting standards as mentioned above. As part of
rebuttal testimony, where appropriate, APS will update forecasted and other
necessary financial information to reflect the more current cost estimates.
In large part, my testimony supports the testimony of other APS witnesses. The
testimony of Mr. Snook focuses on the jurisdictional allocation of APS revenues,
costs, and rate base items for the actual Test Year and all pro forma adjustments.
Ms. Bulkley’s testimony addresses the Company’s ROE.
A. Summary Schedules
Q. PLEASE DESCRIBE THE HISTORICAL AND FORECASTED
INFORMATION ON SFR SCHEDULES A-2 THROUGH A-5.
A. These summary schedules provide the “Summary Results of Operations,” the
“Summary of Capital Structure,” the “Construction Expenditures, Net Plant Placed
in Service and Gross Utility Plant in Service,” and “Summary Changes in Financial
Position” for the Test Year, the prior two calendar years and the next three calendar
years. These schedules include historical and projected information. While the
schedules have been prepared assuming a rate effective date of January 1, 2021,
1 See A.A.C. R14-2-212(G)(2).
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any difference in timing will be addressed in the Company’s subsequent rate filing,
as is typical in a rate case proceeding.
B. Rate Base Schedules
Q. PLEASE DESCRIBE THE INFORMATION ON SFR SCHEDULES B-1
THROUGH B-5.
A. These schedules provide summary and detailed information of our Original Cost
Rate Base (OCRB) and Reconstructed Cost New less Depreciation (RCND) Rate
Base, including the related pro forma adjustments needed to present an adjusted
Rate Base as of the end of the Test Year. I am sponsoring the “Total Company”
portion of these schedules and certain pro forma adjustments. Mr. Snook is
sponsoring the ACC portion, and his testimony will present the allocation of “Total
Company” figures to the ACC jurisdiction.
Q. PLEASE SUMMARIZE THE ADJUSTED TEST YEAR ORIGINAL COST
RATE BASE PROPOSED BY APS.
A. As of June 30, 2019, APS is proposing a Total Company Adjusted OCRB of $11.1
billion. This represents an increase of $376.8 million over the unadjusted amount
and an increase of $3.1 billion from the OCRB found in APS’s last general rate
case. The amount of the adjusted OCRB allocated to the ACC jurisdiction is $8.9
billion. The requested adjustments to the Test Year amounts are summarized in
SFR Schedule B-2, page 5.
Q. WHAT IS MEANT BY THE TERMS “RCND” AND “RCN” AS USED IN
YOUR TESTIMONY?
A. The Commission regulations define RCND as:
An amount consisting of the depreciated reconstruction cost new of the property (exclusive of contributions and/or advances in aid of construction) at the end of the test year, used and useful, plus a proper allowance for working capital and including all applicable pro forma adjustments. Contributions and advances in aid of construction, if recorded in the accounts of the public service corporation, shall be increased to a reconstruction new basis.
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A.A.C. R14-2-103(A)(3)(n).
Thus, Reconstructed Cost New (RCN) refers to the estimated cost of utility
property that would be incurred if APS were to reproduce or reconstruct the
property as new, using current cost levels. RCND is the net amount that results
after deducting accumulated depreciation and amortization (both of which are also
restated in current dollars) from the RCN amount.
Q. WHAT DOES SFR SCHEDULE B-4 PRESENT?
A. SFR Schedule B-4 presents the RCN and RCND amounts of APS’s utility
properties. These amounts were determined by performing an RCN study using
Handy-Whitman indices (or CPI indices for transportation equipment and general
plant not covered by Handy-Whitman). Using these indices has been a long
standing practice by all major utilities in Arizona and accepted by the Commission
and the industry in general for determining the RCN amount.
Q. BASED ON YOUR STUDY, WHAT IS THE RCN OF APS’S UTILITY
PROPERTY DEVOTED TO SERVICE TO THE PUBLIC AS OF THE END
OF THE TEST YEAR?
A. Total RCN for APS’s utility property is $39.6 billion. This total amount is shown
in column (A) of SFR Schedule B-4, page 2 of 2.
Q. WOULD YOU PLEASE EXPLAIN HOW RCND WAS CALCULATED AS
SHOWN ON SFR SCHEDULE B-4?
A. To arrive at RCND, the RCN column (A) is multiplied by a “condition percent,”
also known as a net book value percent, which is shown in column (B). The RCND
is shown in column (C). The condition percent used to convert RCN to RCND is
calculated by first determining the net book value (original cost less accumulated
depreciation and removal costs) for all depreciable plant by each FERC plant
account. This amount is then divided by the original cost by each FERC account
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to arrive at the condition percent. In other words, the condition percent is the
percentage that results when comparing net book value to the original cost of plant
in service.
For example, assume that distribution lines have an original cost of $400,000, and
accumulated depreciation and removal costs of $250,000. The net book value
would be $150,000, which is $400,000 minus $250,000. Also, assume the
distribution lines were purchased in 1985 and have a RCN value of $632,000.
Using these assumptions, the condition percent is calculated by dividing original
cost less accumulated depreciation and removal costs by original cost, or
$150,000/$400,000, resulting in a condition percent of 37.5%. Multiplying the
RCN of $632,000 by the condition percent of 37.5% yields $237,000 of RCND.
Q. ARE THERE ANY OTHER RELATED ADJUSTMENTS NECESSARY TO
DETERMINE FAIR VALUE RATE BASE?
A. Yes. Plant-related Accumulated Deferred Income Taxes (ADIT) were also
adjusted. Plant-related ADIT arises primarily as a result of differences between
book depreciation recorded for GAAP purposes and tax depreciation used for
income tax purposes. Since RCND trending results in a change in accumulated
book depreciation, a corresponding change was made to original cost ADIT. To
make this adjustment, the Company trended plant-related ADIT using the
relationship between the Original Cost less Depreciation and RCND.
Q. WOULD YOU PLEASE EXPLAIN SFR SCHEDULE B-4A?
A. SFR Schedule B-4a shows the computation of adjusted jurisdictional RCND Rate
Base as of June 30, 2019. Column (A) presents data for Total RCND Rate Base.
Mr. Snook provided the jurisdictional allocations of the RCND Rate Base split
between “ACC” and “Other,” which is presented in columns (B) and (C),
respectively.
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Q. HOW DID YOU ARRIVE AT THE AMOUNTS SHOWN ON LINES 9
THROUGH 31 OF SFR SCHEDULE B-4A?
A. The amounts shown on lines 9 through 31 of SFR Schedule B-4a for other Rate
Base elements were obtained from SFR Schedule B-1, page 2 of 2, column (A).
Consistent with past Commission practice, the RCND of these specific Rate Base
elements are stated at their original cost levels, as these elements are assumed not
to change in value with the passage of time, with the exception of deferred income
taxes and regulatory liabilities as a result of excess deferred tax amortization.
Q. WOULD YOU PLEASE EXPLAIN LINES 32 AND 33 OF SFR SCHEDULE
B-4A?
A. The amounts shown on line 32 represent the RCND Rate Base as of June 30, 2019.
However, the end of Test Year data needs to be adjusted to more closely reflect the
value of certain items of property when the proposed rates become effective.
Therefore, it is necessary to also reflect the pro forma Rate Base adjustments in the
RCND Rate Base. The RCND pro forma adjustments are shown in detail in SFR
Schedule B-3. The total pro formas are shown on line 33 of SFR Schedule B-4a.
Q. WHAT IS THE TOTAL ADJUSTED RCND RATE BASE?
A. The Total Company RCND Rate Base, as adjusted, is $19.9 billion. This is shown
in SFR Schedule B-4a, column (A), line 34.
Q. PLEASE EXPLAIN THE COMPUTATION OF WORKING CAPITAL ON
SFR SCHEDULE B-5.
A. SFR Schedule B-5 outlines the computation of the allowance for working capital
of $384.2 million included in the Company’s Rate Base. Working capital is a
measure of investor funding of daily operating expenditures and a variety of non-
plant investments that are necessary to sustain ongoing operations. Working
capital includes materials and supplies, fuel inventories, prepayments and cash
working capital. Working capital is an investment just like other capital
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requirements, such as power plants and transmission and distribution
infrastructure; thus, it is part of APS’s Rate Base. My testimony presents the
calculation of the allowance for working capital, which includes a cash working
capital component that is determined using a lead/lag study. The lead/lag study is
required by Decision No. 55931 (Apr. 1, 1988).
Q. HOW WAS THE CASH WORKING CAPITAL CALCULATED?
A. APS calculated the cash working capital by performing a lead/lag study. A lead/lag
study establishes the amount of investor funds used to maintain utility operations
from the time expenditures are made to the time revenues are collected as a
reimbursement for that utility service. The Company used the number of lead/lag
study days derived from a 12-month period ended June 30, 2019 study and applied
this information to the Test Year income statement expenses.
In addition, the Company considered the pro forma adjustments to the Test Year
income statement expenses and computed a Rate Base pro forma to reflect the
related change in cash working capital (see Section IV Pro Forma Adjustments).
C. Test Year Income Statements
Q. PLEASE DISCUSS THE INFORMATION THAT YOU ARE SPONSORING
ON SFR SCHEDULE C-1.
A. SFR Schedule C-1 is a summary of the Company’s adjusted Test Year income
statement. I am sponsoring the actual Test Year data in the first column of SFR
Schedule C-1, page 1. This information provides the baseline from which pro
forma adjustments are made and shows operating income and net income for the
Test Year.
Q. ARE YOU SPONSORING ANY OTHER RELATED SFR SCHEDULES?
A. Yes. I am sponsoring certain pro forma adjustments on SFR Schedule C-2, which
presents pro forma adjustments to the Company’s Test Year operating income. I
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will discuss these adjustments in detail later in my testimony (see Section IV Pro
Forma Adjustments to Test Year). I am also sponsoring SFR Schedule C-3, which
provides the “Computation of the Gross Revenue Conversion Factor.”
Q. PLEASE DESCRIBE SFR SCHEDULE C-3.
A. SFR Schedule C-3 calculates the factor applied to “gross-up” income to account
for income taxes. The Company applies this factor to operating income to ensure
income tax expense is reflected in the requested revenue requirement. The Gross
Revenue Conversion Factor of 1.3288 (line 5) is an algebraic transformation (1
divided by 1 minus the composite tax rate) of APS’s adjusted Test Year composite
federal and state income tax rate of 24.75% (line 3). This factor is used on SFR
Schedule A-1 (line 7) to arrive at the increase or decrease in Revenue Requirements
necessary to account for income taxes.
D. Cost of Capital
Q. PLEASE DISCUSS THE COST OF CAPITAL INFORMATION THAT YOU
ARE SPONSORING.
A. SFR Schedule D-1 is a summary of the Company’s historical and projected cost of
capital. SFR Schedule D-2 presents supporting detail for the long-term debt
summarized on SFR Schedule D-1. SFR Schedule D-3 addresses preferred stock
and is included in the Company’s schedules for the sake of completeness. SFR
Schedule D-3 is not applicable because APS did not have any outstanding preferred
stock as of June 30, 2019. SFR Schedule D-4 addresses the Company’s cost of
common equity.
Q. WHAT IS THE COST OF CAPITAL THE COMPANY IS REQUESTING?
A. The Company is requesting an adjusted weighted average cost of capital of 7.41%
as set forth on SFR Schedule D-1 (line 5), page 1 of 2.
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Q. PLEASE DISCUSS IN MORE DETAIL THE COMPANY’S
OUTSTANDING LONG-TERM DEBT AS OF THE END OF THE TEST
YEAR.
A. At the end of the Test Year, approximately 97% of APS’s outstanding long-term
debt consisted of unsecured debt with a weighted average interest rate of 4.19%.
Most of the remaining long-term debt consisted of tax-advantaged pollution control
bonds. This debt has a weighted average interest rate of 4.20%.
Q. WHAT WAS APS’S CAPITAL STRUCTURE AT THE END OF THE TEST
YEAR?
A. APS’s total long-term debt and common equity was $10.4 billion. This amount
includes $4.7 billion in long-term debt (including current maturities) and $5.7
billion in common equity. APS’s adjusted capital structure at the end of the Test
Year was 45.33% debt and 54.67% equity.
Q. WHAT ADJUSTMENTS DID YOU MAKE TO THE CAPITAL
STRUCTURE AND COST OF CAPITAL?
A. I have applied two pro forma adjustments to the June 30, 2019 actual capital
structure and cost of capital. The adjustment to the capital structure removes the
impacts to equity of non-cash accounting adjustments for pension and derivatives.
The adjustment to the cost of capital was made specifically to the cost of long-term
debt to reflect the reduction in the cost rate, which occurred immediately after the
Test Year. This adjustment resulted in a reduction to the cost of capital from 4.19%
to 4.10%. While this adjustment is not typically done in a rate case, because of its
proximity to the Test Year, we wanted to pass this benefit on to our customers.
Q. WHAT RETURN ON EQUITY IS THE COMPANY REQUESTING?
A. Ms. Bulkley concludes in her testimony that the fair rate of return on equity for
APS ranges from 10.00% to 10.50%. For the purpose of this filing, the Company
is proposing a return on common equity of 10.15 %.
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E. Financial Statements and Statistical Schedules
Q. PLEASE SUMMARIZE THE INFORMATION PRESENTED ON SFR
SCHEDULES E-1 THROUGH E-9.
A. These schedules relate to historical financial and accounting information as well as
the notes to the financial statements. As noted earlier in my testimony, SFR
Schedule E-6 is only required for combined electric and gas utilities and therefore
does not apply to APS.
Q. PLEASE DISCUSS SFR SCHEDULES E-1 THROUGH E-4.
A. These schedules present APS’s balance sheets, income statements, statements of
changes in financial position, and changes in stockholders’ equity for the Test Year
and the two prior calendar years. As discussed earlier, these financial statements
continue to reflect APS’s unconsolidated results, consistent with previous rate
filings. The SEC Form 10-K and Form 10-Q filings reflect APS’s consolidated
financial statements, which include the consolidation of the Palo Verde (PV) lessor
trusts from which APS leases a portion of PV Unit 2.
Q. PLEASE DISCUSS SFR SCHEDULE E-5.
A. SFR Schedule E-5 is a detailed statement of utility plant included in the Company’s
Rate Base, broken down by FERC account under the Uniform System of Accounts.
The first page of SFR Schedule E-5 is a summary of gross plant in service,
accumulated depreciation and amortization, nuclear fuel, construction work in
progress, plant held for future use and plant acquisition adjustment. The remainder
of the schedule presents supporting detail for each FERC plant account.
Q. WHAT INFORMATION IS PROVIDED ON SFR SCHEDULE E-7?
A. SFR Schedule E-7 provides detailed information concerning APS’s sales (in kWh),
average number of customers, average kWh usage per customer, and average
annual revenue per residential customer over the last three years, including the Test
Year. This information is contained in or derived from APS’s FERC Form 1 and
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Form 3Q filings for the applicable periods. The information in SFR Schedule E-7
is separated by customer classes to show residential, commercial, industrial,
irrigation, public street and highway lighting, other sales to public authorities, and
sales for resale.
Q. PLEASE DISCUSS SFR SCHEDULE E-8.
A. SFR Schedule E-8 provides a breakdown of APS’s tax expense incurred during the
Test Year and the two prior calendar years for federal and state taxes.
Q. PLEASE DISCUSS SFR SCHEDULE E-9.
A. SFR Schedule E-9 presents the Company’s SEC financial statements, including the
footnotes, as filed in the Company’s Form 10-K for 2018, Form 10-Q for the six
months ended June 30, 2018 and the Form 10-Q for the six months ended June 30,
2019. The footnotes include, but are not limited to, the Company’s accounting
policies for depreciation, allowance for funds used during construction and income
taxes. The footnotes also provide additional detailed information related to the
income statements, the balance sheets and statements of cash flows.
F. Projections and Forecasts
Q. PLEASE DISCUSS THE INFORMATION THAT YOU ARE SPONSORING
ON SFR SCHEDULES F-1 THROUGH F-4.
A. SFR Schedule F-1 presents income statements for projected calendar years,
compared with actual Test Year results, at present and proposed rates. As I have
previously indicated, Schedule F-1, like Schedule A-2, shows key information
relating to the Company’s actual and projected ROE. As Schedule F-1 shows,
under APS’s present rates, the Company’s ROE on end-of-year equity falls from
9.9% at the end of the Test Year to under 9% by 2021—well below any reasonable
ROE found in Ms. Bulkley’s testimony as required to maintain the financial health
of APS and ensure access to capital necessary for a robustly growing electric
system. It is important to note that even with the Company’s proposed rates, the
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Company’s ROE in 2021 would still be below the cost of equity capital, but
significantly better than the 8.6% projected under present rates. SFR Schedule F-
2 shows projected changes in the financial position of the Company for future
calendar years compared with the Test Year, at present and proposed rates. SFR
Schedule F-3 presents projected annual capital expenditure requirements, by
property classification, for two and a half years subsequent to the Test Year.
Finally, SFR Schedule F-4 presents the key assumptions used in developing the
projections.
IV. PRO FORMA ADJUSTMENTS TO TEST YEAR
A. Types of Pro Forma Adjustments
Q. WHAT ARE PRO FORMA ADJUSTMENTS?
A. Pro forma adjustments are adjustments made to a historical test year to reflect
conditions during the period in which rates are to be in effect. Because the
Company has used a historical test year, it is necessary to adjust recorded revenues
and expenses for known and measurable changes. Pro forma adjustments
commonly include normalizations, annualizations and out-of-period adjustments.
All of the pro forma adjustments discussed in my testimony reflect Total Company
amounts prior to any jurisdictional allocation and are reflected on either SFR
Schedule B-2 or SFR Schedule C-2.
Q. WHAT ARE “NORMALIZATIONS?”
A. Normalization adjustments compensate or adjust for unusual levels of operations
experienced during the Test Year period. These adjustments generally relate to
items that are abnormal in amount or nonrecurring in nature and are made to better
reflect what is believed to be an ongoing level of operations.
Q. WHAT ARE “ANNUALIZATIONS?”
A. Annualization adjustments recognize that some events occurring during the Test
Year period are ongoing and must be adjusted to reflect their impact over an entire
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12-month period. One example of an annualization is for payroll costs. Since
payroll costs can be higher or lower on an ongoing basis than what was recorded
during the Test Year, an adjustment must be made to reflect the prospective level
of costs.
Q. WHAT IS AN “OUT-OF-PERIOD” OR MISCELLANEOUS
ADJUSTMENT?
A. Out-of-period adjustments remove expenses or revenues properly recorded during
the Test Year, but which are associated with operations from another year.
Miscellaneous adjustments remove costs out of the Test Year for items, which the
Company does not intend to collect from customers.
B. Pro Forma Adjustment Descriptions
1. Remove Test Year Surcharge Revenue and Expense
Q. PLEASE EXPLAIN THE ADJUSTMENT TO REMOVE TEST YEAR
SURCHARGE REVENUES AND EXPENSES.
A. This adjustment is made to exclude from revenue and expense the amounts
collected or refunded during the Test Year under adjustor mechanisms, including
regulatory assessments. Adjustors and regulatory assessments are not collected or
refunded as part of base rates, so they must be excluded from Test Year revenue to
calculate new base rates. The pro forma also removes from expense the associated
costs incurred. This results in an increase to pre-tax operating income of $139.3
million. (See Attachment EAB-1DR and SFR Schedule C-2, page 3, column 7 and
pages 6 through 8, columns 18 through 24.)
2. Include West Phoenix Unit 4 Regulatory Disallowance
Q. PLEASE EXPLAIN THE RATE BASE PRO FORMA ADJUSTMENT FOR
THE WEST PHOENIX UNIT 4 REGULATORY DISALLOWANCE.
A. This disallowance was recorded for regulatory purposes, but did not qualify as a
disallowance for GAAP purposes. Consequently, a pro forma adjustment is needed
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to reduce Rate Base by the disallowed amount. Accordingly, the Rate Base
reduction for the West Phoenix Unit 4 regulatory disallowance at June 30, 2019 is
$5.9 million. (See Attachment EAB-2DR and SFR Schedule B-2, page 3, column
8.)
Q. IS THERE A CORRESPONDING OPERATING INCOME ADJUSTMENT
FOR THE DEPRECIATION EXPENSE RELATED TO THE WEST
PHOENIX UNIT 4 REGULATORY DISALLOWANCE?
A. Yes. The operating income pro forma reflects an annual reduction in depreciation
expense. This results in an increase to pre-tax operating income of $329,000. (See
Attachment EAB-3DR and SFR Schedule C-2, page 10, column 29.)
3. Include Interest Expense on Customer Deposits
Q. PLEASE DESCRIBE THE ADJUSTMENT FOR INTEREST EXPENSE ON
CUSTOMER DEPOSITS.
A. This pro forma adjustment reflects the annualized interest cost associated with
customer deposits as an operating expense. This treatment conforms to the
approach used by the Commission in the Company’s previous rate cases. This
adjustment was calculated by applying the 2.60% annual 2019 interest rate to the
June 30, 2019 outstanding deposit balance. The annual interest rate is the rate
required by APS Schedule 1 for customer deposits—the established one-year
Treasury Constant Maturities rate, effective on the first business day of each year
(in this instance, January 2, 2019), as published on the Federal Reserve website.
The result of this pro forma is a reduction to pre-tax operating income of $2.1
million. (See Attachment EAB-4DR and SFR Schedule C-2, page 11, column 32.)
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4. Adjust Depreciation Expense – 2019 Depreciation Rate Study
Q. WHAT ADJUSTMENTS HAS THE COMPANY MADE TO
DEPRECIATION AND AMORTIZATION EXPENSE?
A. For this filing, APS witness Dr. Ronald E. White performed a 2019 Depreciation
Rate Study using data as of December 31, 2018. Using Dr. White’s study, APS
has updated depreciation rates from the rates authorized in Decision No. 76295
(Aug. 18, 2017). APS is asking Commission approval of these depreciation rates
in this proceeding. Please refer to Dr. White’s testimony for further discussion.
This pro forma adjustment increases depreciation expense and thus results in a
reduction to pre-tax operating income of $89.7 million. (See Attachment EAB-
5DR and SFR Schedule C-2, page 11, column 33.)
Q. DOES THIS PRO FORMA INCREASE MATCH THE 2019
DEPRECIATION RATE STUDY AS SHOWN IN DR. WHITE’S
TESTIMONY?
A. No, it does not match the specific numbers in Dr. White’s 2019 Depreciation Rate
Study, nor should it. The difference between the 2019 Depreciation Rate Study
adjustment of $50.6 million and the pro forma adjustment can be attributed to the
annualization of depreciation expense as well as the inclusion of
depreciation/amortization expense for some General & Intangible assets not
included in Dr. White’s study, such as software.
Q. IS THE COMPANY PROPOSING ANY CHANGES TO ITS EXISTING
AMORTIZATION RATES?
A. No, with one exception. APS is not requesting any change to the amortization rates
authorized in Decision No. 76295, with the exception of the Cholla Unit 2
Regulatory Asset, in which the Company is requesting to apply a straight line
amortization over the original life of the plant versus the accelerated method
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approved in that prior Decision. Refer to the Adjust Cholla Unit 2 Regulatory
Asset Amortization pro forma adjustment below for further information.
5. Adjust for Post-Test Year Plant Additions
Q. WHAT ADJUSTMENTS HAS THE COMPANY MADE TO ACCOUNT
FOR POST-TEST YEAR PLANT ADDITIONS?
A. APS witness Barbara D. Lockwood addresses the details of the Company’s capital
investments in her direct testimony. The Company is proposing to include plant
additions that go into service after the Test Year, but well before new base rates
are expected to be in effect (July 1, 2019 to June 30, 2020). My testimony covers
the mechanics of the pro formas, as discussed below:
Step 1: Construction Work in Progress (CWIP) was extracted from the
general ledger as of June 30, 2019 for non-transmission plant that is
expected to go into service prior to July 1, 2020;
Step 2: The forecast plant in service cost of each project that is expected to
go into service prior to July 1, 2020 was compiled (both projects in CWIP
at June 30, 2019 and projects that begin after June 30, 2019 but are expected
to be completed and in service within 12 months)—growth-related plant
additions are excluded at this point;
Step 3: The plant was classified by functional area: fossil generation,
nuclear generation, distribution, information technology/facilities,
renewables, and technology innovation;
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Step 4: Annual accumulated depreciation and amortization, net of
accumulated deferred income taxes and tax credits (where applicable) were
offset against the post-Test Year plant additions adjustment;
Step 5: The sum of the forecast plant in service costs, less accumulated
depreciation and deferred income taxes, was presented by functional unit
and included in the Rate Base pro forma adjustments that increase Rate Base
at June 30, 2019 by $196.1 million (see Attachment EAB-6DR and SFR
Schedule B-2, pages 1 and 2, columns 2 through 6); and
Step 6: Property taxes, income taxes, and depreciation expense were
calculated and reflected as a reduction to pre-tax operating income of $50.4
million (see Attachment EAB-7DR and SFR Schedule C-2, pages 1 and 2,
columns 1 through 5).
APS will true-up this adjustment with actual plant placed in service, net of
retirements, throughout the case.
6. Adjust Decommissioning Costs
Q. PLEASE EXPLAIN THE NUCLEAR DECOMMISSIONING FUNDS AND
WHAT IS MEANT BY A “QUALIFYING” DECOMMISSIONING FUND.
A. Like all nuclear power plants, Palo Verde eventually will need to be
decommissioned, an expensive and time-consuming process. Regulatory agencies
throughout the country, including the Commission, have required that the cost of
this eventual decommissioning be recovered from electricity customers over the
life of the facility.
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Most of the amounts collected from ratepayers that relate to decommissioning of a
nuclear power plant can be deposited into a “tax-qualified” decommissioning trust.
A trust is “tax-qualified” to the extent it meets certain requirements set forth in the
Internal Revenue Code and related regulations. A “tax-qualified”
decommissioning trust is afforded income tax benefits versus non tax-qualified
trusts. This favorable tax treatment is twofold. Contributions to a qualified
decommissioning trust are deductible for federal income tax purposes in the year
made to the extent these do not exceed the “ruling amount” approved by the U.S.
Secretary of the Treasury in a private letter ruling. The plant owner must request
from the U.S. Secretary of the Treasury a new schedule of ruling amounts upon
each renewal of the operating license of the nuclear power plant. Secondly,
investment earnings of the assets within the trust are taxed at a federal income tax
rate of 20% versus 21% if the investment earnings occurred outside of the “tax-
qualified” trust. The Nuclear Regulatory Commission (NRC) and most state
regulators prefer the external funding option both because of increased security of
the funding for its intended purpose and because of the income tax benefits
afforded “tax-qualified” decommissioning trusts.
Q. PLEASE EXPLAIN THE NEED FOR A PRO FORMA ADJUSTMENT FOR
NUCLEAR DECOMMISSIONING FUNDING AND THE
CORRESPONDING EXPENSE.
A. Two basic components associated with determining the annual amounts to deposit
into the decommissioning fund have changed: earnings assumptions and revised
decommissioning study cost estimates. APS is proposing to keep the funding level
the same at $2,281,000, but with a different allocation of funding to each of the
three units within the trust. The revised decommissioning funding and expense
estimates reflect a 2016 study performed by TLG Services, Inc. The
decommissioning costs in this study are presented in 2016 dollars. An escalation
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rate is used to account for the inflation that will occur between now and the time
of decommissioning. The escalation rate reflects expected increases in
decommissioning costs.
Q. HOW DO THE ASSUMED EARNINGS AND ESCALATION RATES
COMPARE?
A. The earnings assumption is used to determine how much the investments will grow
between now and the time of decommissioning. APS is proposing to use an after-
tax earnings assumption of 4.63% for PV Units 1 and 3 up to 5 years prior to each
Unit’s respective license expiration date and 3.39% thereafter. APS is also
proposing to use an after-tax earnings assumption of 3.39% for PV Unit 2. The
assumed escalation rate in decommissioning costs is 4%. The earnings assumption
for Units 1 and 3 was determined using pre-tax investment return assumptions for
fixed income of 4.25% for the “tax qualified” trusts and 4.00% for the “non-tax
qualified” trusts and pre-tax equity returns of 7.10%. Using a 60% stocks and 40%
bonds asset allocation up to 5 years prior to each Unit’s respective license
expiration date, and a 100% bonds asset allocation thereafter, and the applicable
tax rates the “tax qualified” and “non-tax qualified” trusts, a 4.63% after-tax
earnings assumption was calculated for up to five years prior to each Unit’s
respective license expiration date, and 3.39% thereafter when it is anticipated the
funds will follow a more conservative investment strategy. The Unit 2 assumption
was also determined using a pre-tax investment return assumption for fixed income
of 4.25% for the “tax qualified” trust and 4.00% for the “non-tax qualified” trust.
The Company did not assume an equity return for the Unit 2 trusts due to the
investment restrictions included in the terms of the sale leaseback agreement,
which prohibit Unit 2 from holding equities after January 31, 2010. Therefore, the
after-tax earnings assumption for Unit 2 is 3.39%.
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Q. WHAT IS THE PRO FORMA ADJUSTMENT REQUIRED TO REFLECT
NEW LEVELS OF DECOMMISSIONING TRUST FUNDING?
A. Based on the assumptions described above, the annual level of funding required
remains unchanged at $2,281,000 and does not necessitate a pro forma adjustment.
Q. IS SPECIFIC COMMISSION ACTION REQUIRED?
A. Yes. As previously stated, the owner of a nuclear power plant must request a new
schedule of ruling amounts from the U.S. Secretary of the Treasury upon each
renewal of the operating license of the plant. Treasury Regulation Section 1.468A-
3 states that in the private letter ruling process, the applicant has the burden of
proving that the proposed schedule of ruling amounts is consistent with the
principles of the decommissioning fund provisions, and that it is based on
reasonable assumptions. The Regulation goes on to state: “If a public utility
commission established or approved the currently applicable rates for the
furnishing or sale by the taxpayer of electricity from the plant, the taxpayer can
generally satisfy this burden of proof by demonstrating that the schedule of ruling
amounts is calculated using the assumptions used by the public utility commission
in its most recent order.”
7. Annualize Payroll Expense
Q. PLEASE DESCRIBE THE ADJUSTMENT TO ANNUALIZE PAYROLL
EXPENSE.
A. This pro forma adjustment decreases Test Year expense mainly as a result of a
decrease in average wage levels and fewer employees, partially offset by union pay
increases. This pro forma adjustment annualizes the Test Year payroll and payroll
tax expense to March 2019 employee and wage levels for non-union employees
and to March 2020 employee and wage levels for union employees (per the current
union contract finalized in 2018 and in effect until 2020). This results in an
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increase to pre-tax operating income of $494,000 (see Attachment EAB-8DR and
SFR Schedule C-2, page 12, column 34).
Q. DOES THIS TOTAL PAYROLL ADJUSTMENT ONLY AFFECT O&M?
A. Yes. This adjustment excludes capitalized payroll costs. This O&M adjustment
was estimated by calculating the percentage of APS’s O&M payroll to total payroll
during the Test Year. The total payroll and payroll taxes were allocated to O&M
based on the same Test Year O&M percentage payroll amounts.
8. Normalize Employee Benefits
Q. PLEASE EXPLAIN THE NEED FOR THE EMPLOYEE BENEFIT PRO
FORMA ADJUSTMENT.
A. This adjustment is necessary to appropriately recognize the costs associated with
pension and other post-employment benefit (OPEB) plans, which are primarily
medical benefits for eligible retirees. This adjustment is consistent with the
adjustment recommended by Staff in Decision No. 69663 (Jun. 28, 2007) and used
by the Company in Decision Nos. 71448 (Dec. 30, 2009), 73183 (May 24, 2012)
and 76295.
Q. HOW WAS THE EMPLOYEE BENEFITS PRO FORMA ADJUSTMENT
DETERMINED?
A. The total change in pension and OPEB expense is the difference between the Test
Year expense and the 2019 level of that expense, as determined by our actuaries,
Willis Towers Watson. As noted below, this calculation resulted in an increase to
employee benefits expense.
Q. HOW DID YOU DETERMINE THE AMOUNT OF INCREASED
BENEFITS COSTS PROPERLY ALLOCABLE TO APS’S O&M?
A. An APS allocation factor was calculated and applied to the total Pinnacle West
change in benefit expenses. This allocation factor was determined by dividing
APS’s 12-months ended June 30, 2019 actual O&M employee benefits by the total
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actual employee benefit costs for Pinnacle West for the same 12-month period.
This results in a reduction to pre-tax operating income of $11.3 million (see
Attachment EAB-9DR and SFR Schedule C-2, page 12, column 35).
9. Remove Supplemental Excess Benefit Retirement Plan Expense
Q. PLEASE EXPLAIN THE PRO FORMA ADJUSTMENT TO REMOVE
SERP.
A. This pro forma removes from expense the associated costs of Test Year operations
SERP. This results in an increase to pre-tax operating income of $8.4 million (see
Attachment EAB-10DR and SFR Schedule C-2, page 12, column 36).
10. Remove Stock Compensation
Q. PLEASE EXPLAIN THE PRO FORMA ADJUSTMENT TO REMOVE
STOCK COMPENSATION.
A. The Company proposes to remove the Test Year level of expense associated with
stock compensation. This results in an increase to pre-tax operating income of
$15.9 million (see Attachment EAB-11DR and SFR Schedule C-2, page 13,
column 37).
11. Include Active Union Medical Trust
Q. PLEASE EXPLAIN THE PRO FORMA ADJUSTMENT TO INCLUDE
THE ACTIVE UNION MEDICAL TRUST.
A. The Company proposes to include, for the benefit of customers, the Test Year level
of interest income and realized gain on investments in the Active Union Medical
Trust. This results in an increase to pre-tax operating income of $3.6 million (see
Attachment EAB-12DR and SFR Schedule C-2, page 6, column 16).
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12. Normalize Cash Incentive
Q. PLEASE EXPLAIN THE PRO FORMA ADJUSTMENT TO NORMALIZE
CASH INCENTIVE.
A. The pro forma normalizes the associated costs of Test Year operations for the cash
incentive program over a three-year period. This results in a decrease to pre-tax
operating income of $5.6 million (see Attachment EAB-13DR and SFR Schedule
C-2, page 13, column 38). The use of this three-year normalization of cash
incentive expense was first proposed by Staff and adopted by the Commission in
Decision No. 71448.
13. Normalize Income Tax Expense/Interest Synchronization
Q. WHAT METHODOLOGY DID YOU USE TO DETERMINE THE
FEDERAL AND STATE INCOME TAX PRO FORMA ADJUSTMENT?
A. The Company used a “top down” approach in computing cost-of-service income
tax expense. This calculation, which was also adopted in Decision No. 69663 and
consistently used thereafter, uses the statutory rate and estimated Test Year levels
of various tax credits and other permanent tax items, adjusted for known changes
(e.g., amortization of excess deferred taxes resulting from the Tax Cuts and Jobs
Act), reflecting the Company’s best estimate of on-going income tax expense. It
also considers the deduction of interest expense synchronized to the end of the Test
Year’s Rate Base. The total federal and state income tax pro forma decreases
income tax expense by $5.9 million (see Attachment EAB-14DR and SFR
Schedule C-2, page 13, column 39).
14. Annualize Property Tax Expense
Q. HAS APS PROPOSED AN ADJUSTMENT TO THE TEST YEAR AD
VALOREM (PROPERTY) TAX?
A. Yes. An adjustment is appropriate to reflect June 30, 2019 plant values, the current
state assessment ratios and the most current estimated composite tax rate.
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Q. HOW WERE PROPERTY TAXES CALCULATED?
A. Property taxes were calculated using December 31, 2018 property values as filed
with the Arizona Department of Revenue in April 2019. These property values
were then multiplied by the most current approved assessment ratios. Finally, that
assessed value is multiplied by the actual 2018 composite tax rate. This pro forma
reflects the addition in property tax expense as a result of the Ocotillo
Modernization Project, partially offset by the reductions related to the retirement
of the old Ocotillo Steam Units 1-2 and the shutdown of Navajo Generating Station
(Navajo). As part of rebuttal, APS will update the expected composite tax rate with
the actual rate when it becomes available near the end of the fourth quarter of 2019.
This adjustment results in a reduction to pre-tax operating income of $4.5 million
(see Attachment EAB-15DR and SFR Schedule C-2, page 14, column 40).
15. Include Property Tax Deferral
Q. PLEASE EXPLAIN THE RATE BASE PRO FORMA ADJUSTMENT FOR
THE PROPERTY TAX DEFERRAL.
A. In the 2017 Settlement Agreement, APS was allowed to defer for later recovery or
refund a portion of the changes in its Arizona property taxes (see Decision No.
76295, Exhibit A, Section 11). The terms from Section 11 are as follows:
11.1 APS shall be allowed to defer for future recovery (or credit to customers) the Arizona property tax expense above or below the test year caused by changes to the applicable Arizona composite property tax rate.
11.2 The property tax deferral will not accrue interest during the deferral period, unless it is negative, in which case, it will accrue interest in favor of APS’s customers at APS’s short term debt rate.
11.3 Beginning with the effective date of the Commission decision resulting from APS’s next general rate case, any final property tax rate deferral that has a positive balance will be recovered from customers over 10 years, with a return at APS’s short term debt rate, also with a return on any unrefunded negative balance at the same short term debt rate.
11.4 The Signing Parties reserve the right to review APS’s property tax deferrals in APS’s next general rate case for reasonableness and prudence.
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11.5 Prior to the next APS general rate case, APS will meet and confer with Staff, RUCO and other stakeholders regarding the appropriate ratemaking treatment for the two year lag on payment of property taxes for post-test year plant.
APS is including, in the pro forma, the amount of the deferral to what it will be on
December 31, 2020. Accordingly, the Rate Base reduction for the property tax
deferral at December 31, 2020 is $1.7 million (see Attachment EAB-16DR and
SFR Schedule B-2, page 3, column 9).
In accordance with Paragraph 11.5 of the Settlement Agreement, APS met and
conferred with Staff and RUCO in September 2019 and agreed to consistently
include property taxes for post-test year plant in line with other utilities and public
utility commission decisions and to also give customers the benefit of the lag
between assessment and payment of property taxes in the cash working capital
lead/lag study.
Q. IS THERE A CORRESPONDING OPERATING INCOME ADJUSTMENT
FOR THE PROPERTY TAX DEFERRAL ADJUSTMENT?
A. Yes. The operating income pro forma reflects the adjustment to amortize the
property tax deferral over ten years, as authorized in Decision No. 76295. This
results in an increase to pre-tax operating income of $590,000 (see Attachment
EAB-17DR and SFR Schedule C-2, page 14, column 41).
16. Annualize Four Corners Coal Reclamation Costs
Q. PLEASE DESCRIBE THE PRO FORMA TO ANNUALIZE FOUR
CORNERS COAL RECLAMATION COSTS.
A. This pro forma adjustment for Four Corners’ coal reclamation annualizes the
estimate for final reclamation costs, the costs to account for inflation, and the
amortization period for Units 1-5. The estimate for final reclamation costs is based
on a study performed by Golder Associates as of September 2019. The costs within
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the Golder Associates study were presented on a December 2019 dollar basis. Due
to the long-term nature of these costs, APS escalated the cost estimates for Units
1-5 through June 2031, which is aligned with the term of the coal supply agreement.
The Company is using an amortization period to June 2038, which is aligned with
end of plant life. The result is an increase to pre-tax operating income of $3.1
million (see Attachment EAB-18DR and SFR Schedule C-2, page 15, column 43).
Q. HOW WAS THE ESCALATION CALCULATED?
A. Total estimated costs from the Golder Associates study were used to derive APS’s
share of Four Corners coal reclamation (in 2019 dollars). The reclamation costs
for Units 1-5 are inflated using an annual rate of 4% over 12.5 years to adjust the
2019 dollar basis to second quarter 2031, which is the end of the coal contract. Per
the current coal supply agreement, APS shall fund Final Reclamation in 13 equal
annual installments, on August 1 of each Contract Year (beginning August 2018)
into an irrevocable escrow account, solely dedicated to the Final Reclamation Costs
of the Navajo Mine (the Escrow Account). The funding will be based on the initial
final reclamation estimates with true-ups for updates of estimates made
periodically. The Company is using an amortization period to June 2038, which is
aligned with end of plant life.
17. Annualize Navajo Coal Reclamation Costs
Q. PLEASE DESCRIBE THE PRO FORMA TO ANNUALIZE NAVAJO
COAL RECLAMATION COSTS.
A. This pro forma adjustment for Navajo coal reclamation annualizes the estimate for
final reclamation costs, the costs to account for growth, and the amortization
period. The estimate for final reclamation costs is based on a study performed by
Golder Associates as of December 2017. The calculation of the estimate for final
reclamation costs uses the Golder Associates study, net of any prior negotiated
settlements or funding, and updated for the composite index change and the
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earnings rate. The final reclamation estimate is amortized over the coal supply
agreement to December 22, 2019. Payments are made monthly to the coal supplier,
Peabody, based on costs and coal usage. This results in a reduction to pre-tax
operating income of $1.9 million (see Attachment EAB-19DR and SFR Schedule
C-2, page 15, column 44).
Q. HOW WAS THE ESCALATION CALCULATED?
A. Total estimated costs from the 2017 Golder Associates study were used to derive
APS’s share of Navajo coal reclamation costs (adjusted for composite index
changes and earning rate for 2020 dollars). The reclamation costs are inflated using
an annual rate of 2.5% to 2020. The final reclamation costs are amortized through
April 2026. Payments are made monthly to Peabody based on reclamation
obligation and coal usage.
18. Adjust Cash Working Capital for Cost of Service
Q. PLEASE DESCRIBE THE PRO FORMA TO ADJUST CASH WORKING
CAPITAL FOR COST OF SERVICE PRO FORMAS.
A. This is a Rate Base pro forma to adjust cash working capital to include the effects
of the cost of service pro formas. As discussed earlier in my testimony, the cash
working capital on SFR Schedule B-5 includes a cash working capital component
determined using a lead/lag study. The expense levels in that study reflect the
actual expense in the Test Year. This pro forma adjusts the study to take into
consideration the cost of service pro formas which adjust actual Test Year levels
of expense. This pro forma decreases Rate Base at June 30, 2019 by $10.5 million
(see Attachment EAB-20DR and SFR Schedule B-2, page 4, column 10).
Q. ARE THERE ANY ADDITIONAL IMPACTS OF THIS RATE BASE PRO
FORMA?
A. Yes. Since the Rate Base pro forma affects total Rate Base, there is a
corresponding operating income pro forma necessary to reflect the income tax
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impacts of interest. This pro forma was calculated using the Rate Base adjustment
above and the weighted cost of debt. This adjustment increases income tax expense
by $48,000 (see Attachment EAB-21DR and SFR Schedule C-2, page 15, column
45).
19. Normalize Fossil and Nuclear Maintenance Expenses
Q. CAN YOU PLEASE DESCRIBE THE PRO FORMAS TO NORMALIZE
NUCLEAR AND FOSSIL MAINTENANCE?
A. Yes. These pro formas adjust both planned maintenance time and unplanned
outage time so that the level of maintenance expense included in the Test Year is
consistent with an average year. These adjustments are necessary because outage
time at each of the power plants in the Test Year for planned routine maintenance
and unplanned forced outages is not indicative of the normal levels of availability.
APS adjusted Test Year O&M expenses to normalize maintenance levels for the
Company’s production plant in service at June 30, 2019. This was done separately
for the Company’s nuclear facilities and its fossil facilities. The nuclear generation
maintenance adjustment reduces pre-tax operating income by $1.4 million and the
fossil generation maintenance adjustment reduces pre-tax operating income by
$5.9 million. The O&M expense adjustments include the impacts of the outage
time normalization for all of the units. (See Attachments EAB-22DR and EAB-
23DR and SFR Schedule C-2, page 16, columns 47 and 48.)
Q. HOW DID YOU ADJUST THE OUTAGE TIME TO NORMALIZE THE
TEST YEAR RESULTS?
A. Planned maintenance time for each non-nuclear generating plant is an average over
the routine overhaul cycle for the plant type. For example, the Company’s coal
plants are on a six-year overhaul cycle, which means that each of the coal units
should experience a major overhaul once in every six-year period. The specific
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six-year period applicable to the normalization includes the historical years of
2014—12-months ended June 30, 2019.
Normalized PV outage time is calculated in a similar manner, using a three-year
period spanning 2017—12-months ended June 30, 2019, but the rationale is
slightly different than the one applicable to the coal plant outage time
normalization. The nuclear units are each on an 18-month refueling cycle, so a
three-year period ensures that each unit’s maintenance time is reflected in equal
proportion in the normalization period. Any single year, such as the Test Year,
does not represent the average maintenance time and associated expense levels that
can reasonably be expected when rates established in this case will be in effect.
Q. HOW DID YOU ADJUST THE MAINTENANCE EXPENSES TO
NORMALIZE THE TEST YEAR RESULTS?
A. The maintenance expenses were normalized in a similar fashion to the outage time.
For fossil generating units, normal maintenance levels are determined by averaging
the historical maintenance expense at each power plant using the six-year average
maintenance cycle. Normal PV expenses are based on historical expenses for a
three-year period.
Labor costs, including overtime costs, have been adjusted to reflect historical labor
cost increases. Non-labor maintenance costs were adjusted to current cost levels
using the relevant Handy-Whitman cost indices.
20. Adjust Sundance Maintenance Expense Accrual
Q. PLEASE DESCRIBE THE PRO FORMA TO ADJUST THE SUNDANCE
MAINTENANCE EXPENSE ACCRUAL.
A. This pro forma annualizes the accrual of the overhaul maintenance costs associated
with the Sundance Units as authorized in Decision No. 69663. This adjustment
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results in a reduction to pre-tax operating income of $1.5 million (see Attachment
EAB-24DR and SFR Schedule C-2, page 17, column 49).
21. Remove Navajo Power Plant Costs
Q. PLEASE DESCRIBE THE PRO FORMA TO REMOVE NAVAJO POWER
PLANT COSTS.
A. This pro forma removes the Test Year operations and maintenance expense as well
as administrative and general expenses as a result of the anticipated closure of
Navajo in December 2019. This adjustment results in an increase to pre-tax
operating income of $16.5 million (see Attachment EAB-25DR and SFR Schedule
C-2, page 10, column 30).
22. Include Ocotillo Modernization Project Deferral
Q. PLEASE DESCRIBE THE RATE BASE PRO FORMA ADJUSTMENT TO
INCLUDE OCOTILLO MODERNIZATION PROJECT DEFERRAL.
A. In the 2017 Settlement Agreement, APS was allowed to defer for later recovery the
costs related to the Ocotillo Modernization Project (see Decision No. 76295,
Exhibit A, Section 10). The terms from Section 10 are as follows:
10.1 APS will be authorized to defer for possible later recovery through rates, all non-fuel costs (as defined herein to include all O&M, property taxes, depreciation, and a return at APS’s embedded cost of debt in this proceeding) of owning, operating, and maintaining the Ocotillo Modernization Project (“OMP”) and retiring the existing steam generation at Ocotillo. Nothing in this paragraph shall be construed in any way to limit the Commission’s authority to review the entirety of the project and to make any disallowances thereof due to imprudence, errors or inappropriate application of the requirements of this Decision. The interest component of the Ocotillo deferral will be set at APS’s embedded cost of debt established in this Agreement.
10.2 The entire OMP will be in service before the rate effective date of APS’s next general rate case, and the entire OMP investment will be addressed and resolved in that proceeding.
10.3 This agreement does not address the prudence of the OMP, and a deferral of the OMP costs does not guarantee recovery of those costs. Consideration of OMP in APS’s next general rate case does not create any precedent, guarantee, or certainty regarding the consideration or treatment of post-test year plant.
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This pro forma adjusts the Test Year to include the deferral amount of the Ocotillo
Modernization Project from July 1, 2019 through December 31, 2020.
Accordingly, the Rate Base increase for the Ocotillo Modernization Project
deferral at December 31, 2020 is $62.0 million (see Attachment EAB-26DR and
SFR Schedule B-2, page 4, column 11).
Q. IS THERE A CORRESPONDING OPERATING INCOME ADJUSTMENT
FOR THE OMP DEFERRAL ADJUSTMENT?
A. Yes. The operating income pro forma reflects the adjustment to amortize the
Ocotillo Modernization Project deferral over ten years, as authorized in Decision
No. 76295. This results in a decrease to pre-tax operating income of $9.2 million
(see Attachment EAB-27DR and SFR Schedule C-2, page 9, column 26).
Q. ARE THERE ANY ADDITIONAL ADJUSTMENTS TO THE TEST YEAR
AS A RESULT OF THE OCOTILLO MODERNIZATION PROJECT?
A. Yes. The Ocotillo on-going operation and maintenance normalization pro forma
reflects the ongoing continuing operations of the Ocotillo Power Plant with the
retirement of the two steam units and the addition of the new units. This results in
a decrease to pre-tax operating income of $6.7 million (see Attachment EAB-28DR
and SFR Schedule C-2, page 11, column 31).
23. Include Four Corners Selective Catalytic Reduction Deferral
Q. PLEASE DESCRIBE THE RATE BASE PRO FORMA ADJUSTMENT TO
INCLUDE FOUR CORNERS SELECTIVE CATALYTIC REDUCTION
(SCR) DEFERRAL.
A. In the 2017 Settlement Agreement, APS was allowed to defer for later recovery, in
a subsequent filing to the Decision, the costs related to the SCRs (see Decision No.
76295, Exhibit A, Section 9, Paragraphs 9.1, 9.2, and 9.3). The terms from Section
9 are as follows:
9.1 The parties agree that this Docket shall remain open for the sole purpose of allowing APS to file a request that its rates be adjusted no later than January 1, 2019 to reflect the proposed addition of
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Selective Catalytic Reduction (“SCR”) equipment at Four Corners, as requested in APS’s application in this Docket.
9.2 APS shall be authorized by the Commission to defer for possible later recovery through rates, all non-fuel costs (as defined herein to include all O&M, property taxes, depreciation, and a return at APS’s embedded cost of debt in this proceeding) of owning, operating and maintaining the Selective Catalytic Reduction environmental controls at the Four Corners Power Plant from the date such controls go into service until the inclusion of such costs into rates. Nothing in this paragraph shall be construed in any way to limit this Commission’s authority to review the entirety of the project and to make any disallowances thereof due to imprudence, errors or inappropriate application of the requirements of this Decision. The interest component of the SCR deferral will be set at APS’s embedded cost of debt established in this Agreement.
9.3 Any filing seeking a rate adjustment pursuant to Section 9.1 shall include the following schedules: (1) the most current APS balance sheet at the time of filing; (2) the most current APS income statement at the time of filing; (3) an earnings schedule that demonstrates that the operating income resulting from the rate adjustment does not result in a return on rate base in excess of that authorized by this Agreement in the period after the rate adjustment becomes effective; (4) a revenue requirement calculation, including the amortization of any deferred costs; (5) an adjusted rate base schedule; and (6) a typical bill analysis under present and filed rates. The Signing Parties agree to use good faith efforts to process this rate adjustment request such that any resulting rate adjustment becomes effective no later than January 1, 2019, pursuant to Section 9.1.
APS is including, in the pro forma, the amount of the deferral to what it will be at
December 31, 2020. Accordingly, the Rate Base increase for the SCR is $33.2
million (see Attachment EAB-29DR and SFR Schedule B-2, page 4, column 12).
Q. IS THERE A CORRESPONDING OPERATING INCOME ADJUSTMENT
FOR THE SCR DEFERRAL ADJUSTMENT?
A. Yes. The operating income pro forma reflects the adjustment to amortize the SCR
deferral over ten years. This results in a decrease to pre-tax operating income of
$8.3 million (see Attachment EAB-30DR and SFR Schedule C-2, page 9, column
25).
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24. Include Cholla Inventory
Q. PLEASE EXPLAIN THE PRO FORMA ADJUSTMENT TO INCLUDE
CHOLLA INVENTORY.
A. The Company proposes to include for recovery the annualized level of amortization
related to Cholla material and supplies inventory as a result of the anticipated
closure of the coal plant and cost recovery of the remaining inventory balance.
This results in a decrease to pre-tax operating income of $1.5 million (see
Attachment EAB-31DR and SFR Schedule C-2, page 10, column 28).
25. Include Four Corners Inventory
Q. PLEASE EXPLAIN THE PRO FORMA ADJUSTMENT TO INCLUDE
FOUR CORNERS INVENTORY.
A. Similar to the pro forma above, the Company proposes to include for recovery the
annualized level of amortization related to Four Corners material and supplies
inventory. This results in a decrease to pre-tax operating income of $1.0 million
(see Attachment EAB-32DR and SFR Schedule C-2, page 9, column 27).
26. Normalize Advertising Expense
Q. PLEASE EXPLAIN THE PRO FORMA ADJUSTMENT TO NORMALIZE
ADVERTISING EXPENSE.
A. The pro forma removes from expense the associated costs of Test Year operations
to normalize advertising expense over a three-year period. This results in an
increase to pre-tax operating income of $2.3 million (see Attachment EAB-33DR
and SFR Schedule C-2, page 16, column 46). Please note that advertising costs not
normally allowed for ratemaking purposes are excluded from this normalized
amount as part of Adjustment 29, described later in my testimony.
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27. Include Removal Costs Associated with West Phoenix
Q. PLEASE DESCRIBE THE PRO FORMA TO INCLUDE FOR RECOVERY
THE REMOVAL COSTS ASSOCIATED WITH THE CLOSURE AND
DECOMMISSIONING OF WEST PHOENIX.
A. This pro forma includes the recovery of additional removal costs associated with
the closure and subsequent decommissioning of West Phoenix Steam Units. This
adjustment results in a decrease to pre-tax operating income of $998,000 (see
Attachment EAB-34DR and SFR Schedule C-2, page 14, column 42).
28. Include Fire Mitigation Costs
Q. PLEASE DESCRIBE THE PRO FORMA TO INCLUDE THE COSTS
ASSOCIATED WITH THE COMPANY’S FIRE MITIGATION
PROGRAM.
A. This pro forma includes the anticipated increases in operations and maintenance
costs related to the Company’s fire mitigation program. This adjustment results in
a decrease to pre-tax operating income of $3.3 million (see Attachment EAB-35DR
and SFR Schedule C-2, page 6, column 17).
29. Include Customer Affordability Benefits
Q. PLEASE DESCRIBE THE PRO FORMA TO INCLUDE THE BENEFITS
ASSOCIATED WITH THE COMPANY’S CUSTOMER AFFORDABILITY
PROGRAM.
A. As discussed by APS witnesses Ms. Lockwood and Jeffrey B. Guldner, this pro
forma includes the anticipated cost reduction and on-going level of benefit to
customers as a result of the Customer Affordability Program currently being
initiated and implemented by the Company. This adjustment results in an increase
to pre-tax operating income of $17.8 million (see Attachment EAB-36DR and SFR
Schedule C-2, page 5, column 15).
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30. Remove Out of Period and Miscellaneous Items
Q. PLEASE DESCRIBE THE PRO FORMA TO REMOVE
MISCELLANEOUS AND OUT OF PERIOD ITEMS.
A. In any test year, there are some items recorded that relate to periods other than the
test year, or conversely, items recorded in other time periods that correctly belong
in the test year. For the 12-months ended June 30, 2019 Test Year, APS is
removing costs associated with consulting fees, miscellaneous advertising and
other general expenses that are not reflective of on-going costs, or are costs that
APS does not intend to collect from customers. This adjustment, for the sake of
simplicity, combines several smaller entries that fit this description and are shown
in aggregate in the pro forma. This adjustment results in an increase to pre-tax
operating income of $14.2 million (see Attachment EAB-37DR and SFR Schedule
C-2, page 17, column 50).
31. Include Cloud Computing Deferral
Q. PLEASE DESCRIBE THE RATE BASE PRO FORMA ADJUSTMENT TO
INCLUDE THE IMPACTS OF CLOUD COMPUTING.
A. This is a Rate Base pro forma to include the impacts associated with cloud
computing in alignment with NARUC’s Cloud Computing Resolution (see
Resolution Encouraging State Utility Commissions to Consider Improving the
Regulatory Treatment of Cloud Computing Arrangements, Nov. 16, 2016), as
follows:
…WHEREAS, Utilities should be free to make software investments based on which option best meets both the needs of the utility and its customers, rather than how the investment will be treated for accounting purposes; and
WHEREAS, The existing regulatory accounting rules may be interpreted, if appropriate, to allow for utilities to capitalize cloud-based software; and
WHEREAS, Regardless of how cloud computing is treated for regulatory accounting purposes, regulators will still examine whether the investment is prudent; now, therefore be it
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RESOLVED, That the Board of Directors of the National Association of Regulatory Utility Commissioners (NARUC), convened at its 2016 Annual Meetings in La Quinta, California, recognizes that utilities best serve customers, society, the environment, and the grid by making software procurement decisions regardless of the delivery method or payment model; and be it further
RESOLVED, That NARUC encourages State regulators to consider whether cloud computing and on-premise solutions should receive similar regulatory accounting treatment, in that both would be eligible to earn a rate of return and would be paid for out of a utility’s capital budget.
This pro forma is calculated by taking the annual level of cloud computing costs
associated with applications in which contracts have been entered into and
multiplying that by the average contract term of 3.2 years. This pro forma increases
Rate Base at June 30, 2019 by $12.8 million (see Attachment EAB-38DR and SFR
Schedule B-2, page 3, column 7).
32. Include Amortization of Excess Deferred Tax (TEAM III)
Q. PLEASE DESCRIBE THE RATE BASE PRO FORMA ADJUSTMENT TO
INCLUDE THE EXCESS DEFERRED TAX ASSOCIATED WITH THE
TEAM III ADJUSTOR MECHANISM.
A. This is a Rate Base pro forma to adjust the Test Year to reflect amortization of
excess deferred taxes associated with the Company’s TEAM III mechanism
assuming amortization begins January 1, 2020 and rates associated with this rate
case do not go into effect until January 1, 2021. This pro forma increases Rate
Base at June 30, 2019 by $90.7 million (see Attachment EAB-39DR and SFR
Schedule B-2, page 5, column 13).
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33. Adjust Cholla Unit 2 Regulatory Asset Amortization
Q. PLEASE DESCRIBE THE PRO FORMA TO ADJUST THE CHOLLA
UNIT 2 REGULATORY ASSET AMORTIZATION.
A. The Company proposes to include this pro forma, which adjusts the Test Year to
reflect the impacts of amortizing the Cholla Unit 2 regulatory asset over the
remaining plant life instead of the accelerated method approved in the 2017
Settlement Agreement. This adjustment results in an increase to pre-tax operating
income of $11.5 million (see Attachment EAB-40DR and SFR Schedule C-2, page
17, column 51).
V. REQUEST FOR PROPERTY TAX DEFERRAL
Q. IS APS PROPOSING TO RECEIVE AUTHORIZATION FOR A
PROPERTY TAX DEFERRAL?
A. Yes, a property tax deferral is necessary and important to mitigate the risk of
changes in property tax rates within Arizona. For most companies, the assessed
value of property rises and falls with its market value. As values fall, the state and
local taxing entities raise rates in an attempt to maintain revenues. An increase in
the property tax rate to account for any lower assessed value would not necessarily
change that non-utility taxpayer’s tax payment. For APS, however, the assessed
value of APS property is based on its book value—a value that in total is usually
steady or rising. Thus, when a taxing entity increases or decreases its tax rate,
APS’s tax payment necessarily rises or falls accordingly. APS is concerned that
its property tax rate and related property tax expense could increase significantly,
much like it has over the past few years. APS proposes to continue the Arizona
property tax deferral and structure it similarly to the one approved in the last rate
case.
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Q. PLEASE DESCRIBE THE PROPOSED PROPERTY TAX DEFERRAL
TERMS.
A. APS proposes to be allowed to defer for future recovery, in accordance with the
provisions of Accounting Standards Codification (ASC) 980 (formerly SFAS No.
71), 100% of all changes to Arizona property tax expense above or below the
Adjusted Test Year level of $177 million caused by changes to the applicable
Arizona composite property tax rate (not changes in the assessed value of
property). APS will track and record the deferral in the same manner as it currently
is and propose the recovery of the deferred balance in the next rate case. Similarly,
to past practice, APS proposes to recover any positive balance from customers over
ten years and any negative balance will be refunded to customers over three years.
VI. CONCLUSION
Q. DOES THIS CONCLUDE YOUR DIRECT TESTIMONY?
A. Yes.
Remove Test Year Surcharge Revenue
and Expense
Line No. Description
Electric Operating Revenues1. Revenues from Base Rates -$ 2. Revenues from Surcharges (128,995) 3. Other Electric Revenues - 4. Total Electric Operating Revenues (128,995)
5. Electric Fuel and Purchased Power Costs (129,528) 6. Oper Rev Less Fuel & Purch Pwr Costs 533
Other Operating Expenses:7. Operations Excluding Fuel Expense (138,722) 8. Maintenance - 9. Subtotal (138,722)
10. Depreciation and Amortization - 11. Amortization of Gain - 12. Administrative and General - 13. Other Taxes - 14. Total Other Operating Expense (138,722)
15. Operating Income Before Income Tax 139,255
16. Interest Expense - 17. Taxable Income 139,255
18. Current Income Tax Rate - 24.75% 34,466
19. Operating Income (line 15 minus line 18) 104,789$
(Dollars in Thousands)
Adjustment to Test Year operations to remove surchage revenue and expense.
Attachment EAB-1DRPage 1 of 1
ARIZONA PUBLIC SERVICE COMPANYIncome Statement Pro Forma Adjustments
Test Year Ended 6/30/2019
Include West Phoenix Unit 4Regulatory Disallowance
LineNo. Description
1. Gross Utility Plant in Service (13,833)$
2. Less: Accumulated Depreciation & Amort. (6,432)
3. Net Utility Plant in Service (7,401)
4. Less: Total Deductions (1,502)
5. Total Additions -
6. Total Rate Base (5,899)$
(Dollars in Thousands)
Adjustment to Test Year rate base to include the regulatory disallowance for West Phoenix CC Unit 4 as required by ACC Decision Nos. 67744 and 69663.
Attachment EAB-2DRPage 1 of 1
ARIZONA PUBLIC SERVICE COMPANYRate Base Pro Forma Adjustments
Period Ended 6/30/2019
LineNo. Description
Electric Operating Revenues1. Revenues from Base Rates -$ 2. Revenues from Surcharges - 3. Other Electric Revenues - 4. Total Electric Operating Revenues -
5. Electric Fuel and Purchased Power Costs - 6. Oper Rev Less Fuel & Purch Pwr Costs -
Other Operating Expenses:7. Operations Excluding Fuel Expense - 8. Maintenance - 9. Subtotal -
10. Depreciation and Amortization (329) 11. Amortization of Gain - 12. Administrative and General - 13. Other Taxes - 14. Total Other Operating Expenses (329)
15. Operating Income Before Income Tax 329
16. Interest Expense (110) 17. Taxable Income 439
18. Current Income Tax Rate - 24.75% 109
19. Operating Income (line 15 minus line 18) 220$
(Dollars in Thousands)
Include West Phoenix Unit 4 Regulatory Disallowance
Adjustment to Test Year operations to reflect amortization of regulatory disallowance of West Phoenix Unit 4 over the remaining life of the plant as required by previous Decision Nos. 67744 and 69663.
Attachment EAB-3DRPage 1 of 1
ARIZONA PUBLIC SERVICE COMPANYIncome Statement Pro Forma Adjustments
Test Year Ended 6/30/2019
LineNo. Description
Electric Operating Revenues1. Revenues from Base Rates -$ 2. Revenues from Surcharges - 3. Other Electric Revenues - 4. Total Electric Operating Revenues -
5. Electric Fuel and Purchased Power Costs - 6. Oper Rev Less Fuel & Purch Pwr Costs -
Other Operating Expenses:7. Operations Excluding Fuel Expense 2,117 8. Maintenance - 9. Subtotal 2,117
10. Depreciation and Amortization - 11. Amortization of Gain - 12. Administrative and General - 13. Other Taxes - 14. Total Other Operating Expense 2,117
15. Operating Income Before Income Tax (2,117)
16. Interest Expense - 17. Taxable Income (2,117)
18. Current Income Tax Rate - 24.75% (524)
19. Operating Income (line 15 minus line 18) (1,593)$
(Dollars in Thousands)
Include Interest Expense on Customer Deposits
Adjustment to Test Year operations to reflect the operating income impact of interest on customer deposits using January 2019 interest rates.
Attachment EAB-4DRPage 1 of 1
ARIZONA PUBLIC SERVICE COMPANYIncome Statement Pro Forma Adjustments
Test Year Ended 6/30/2019
Line No. Description
Adjust Depreciation Expense - 2019
Depreciation Rate Study
Electric Operating Revenues -$
1. Revenues from Base Rates - 2. Revenues from Surcharges - 3. Other Electric Revenues - 4. Total Electric Operating Revenues -
5. Electric Fuel and Purchased Power Costs - 6. Oper Rev Less Fuel & Purch Pwr Costs -
Other Operating Expenses:7. Operations Excluding Fuel Expense -
8. Maintenance - 9. Subtotal -
10. Depreciation and Amortization 89,703 11. Amortization of Gain - 12. Administrative and General - 13. Other Taxes - 14. Total Other Operating Expense 89,703
15. Operating Income Before Income Tax (89,703)
16. Interest Expense - 17. Taxable Income (89,703)
18. Current Income Tax Rate - 24.75% (22,202)
19. Operating Income (line 15 minus line 18) (67,501)$
Adjustment to Test Year operations to reflect depreciation expense based on the 2019 Depreciation Rate Study.
Attachment EAB-5DRPage 1 of 1
ARIZONA PUBLIC SERVICE COMPANYIncome Statement Pro Forma Adjustments
Test Year Ended 6/30/19(Dollars in Thousands)
Line
No. Description
Fossil Generation Post-Test Year Plant
Additions
Nuclear Generation Post-Test Year Plant Additions
Distribution and IT Facilities Post-Test Year Plant
Additions
Renewables Post-Test Year Plant Additions
Technology Innovation Post-Test Year Plant
Additions
Total Company Post-Test Year Plant Additions
1. Gross Utility Plant in Service 179,664$ 73,326$ 470,435$ 24,364$ 25,446$ 773,236$
2. Less: Accumulated Depreciation and Amort. 201,688 36,557 287,026 33,094 - 558,365
3. Net Utility Plant in Service (22,024) 36,769 183,409 (8,730) 25,446 214,871
4. Less: Total Deductions 10,896 (1,037) 5,634 3,120 777 19,390
5. Total Additions - - - 635 - 635
6. Total Rate Base (32,920)$ 37,806$ 177,775$ (11,215)$ 24,669$ 196,116$
Attachment EAB-6DRPage 1 of 1
Adjustments to Test Year Rate Base to include Post-Test Year plant additions.
Arizona Public Service CompanyRate Base Pro Forma Adjustments
Test Year Ended 6/30/2019(Dollars in Thousands)
LineFossil Generation Post-
Test YearNuclear Generation
Post-Test Year
Distribution and IT/Facilities
Post-Test Year
Technology Innovation
Post-Test YearRenewables Post-Test
Year Total Company Post-Test Year
No. Description Plant Additions Plant Additions Plant Additions Plant Additions Plant Additions Plant Additions
Electric Operating Revenues1. Revenues from Base Rates -$ -$ -$ -$ -$ -$ 2. Revenues from Surcharges - - - - - - 3. Other Electric Revenues - - - - - - 4. Total Electric Operating Revenues - - - - - -
5. Electric Fuel and Purchased Power Costs - - - - - - 6. Oper Rev Less Fuel & Purch Pwr Costs - - - - - -
O her Operating Expenses:7. Operations Excluding Fuel Expense - - - - - - 8. Maintenance - - - - - - 9. Subtotal - - - - - -
10. Depreciation and Amortization 8,337 704 26,552 2,545 926 39,064 11. Amortization of Gain - - - - - - 12. Administrative and General - - - - - - 13. Other Taxes 1,209 495 9,084 480 97 11,365 14. Total Other Operating Expense 9,546 1,199 35,636 3,025 1,023 50,429
15. Operating Income Before Income Tax (9,546) (1,199) (35,636) (3,025) (1,023) (50,429)
16. Interest Expense 1.86% (410) 684 3,411 473 (162) 3,997 17. Taxable Income (9,136) (1,883) (39,047) (3,498) (860) (54,425)
18. Current Income Tax Rate 24.75% (2,261) (466) (9,664) (866) (213) (13,471)
19. Operating Income (line 15 minus line 18) (7,285)$ (733)$ (25,972)$ (2,159)$ (810)$ (36,958)$
(Dollars in Thousands)
Adjustment to Test Year operations to include depreciation, interest expense, property taxes and reduced income tax expense associated with Fossil Generation, Nuclear Generation, Distribution and IT/Facili ies, Technology Innovation, Renewables and Modern Grid Post-Test Year Plant Additions.
Attachment EAB-7DRPage 1 of 1
ARIZONA PUBLIC SERVICE COMPANYIncome Statement Pro Forma Adjustments
Test Year Ended 6/30/2019
LineNo. Description
Electric Operating Revenues1. Revenues from Base Rates -$ 2. Revenues from Surcharges - 3. Other Electric Revenues - 4. Total Electric Operating Revenues -
5. Electric Fuel and Purchased Power Costs - 6. Oper Rev Less Fuel & Purch Pwr Costs -
Other Operating Expenses:7. Operations Excluding Fuel Expense (410) 8. Maintenance (84) 9. Subtotal (494)
10. Depreciation and Amortization - 11. Amortization of Gain - 12. Administrative and General - 13. Other Taxes - 14. Total Other Operating Expense (494)
15. Operating Income Before Income Tax 494
16. Interest Expense - 17. Taxable Income 494
18. Current Income Tax Rate - 24.75% 122
19. Operating Income (line 15 minus line 18) 372$
(Dollars in Thousands)
Annualize Payroll Expense
Adjustment to Test Year operations to reflect the annualization of payroll, payroll tax and non-retirement benefit expenses to March 2019 employee levels for performance review and March 2020 Union employees.
Attachment EAB-8DRPage 1 of 1
ARIZONA PUBLIC SERVICE COMPANYIncome Statement Pro Forma Adjustments
Test Year Ended 6/30/2019
LineNo. Description
Electric Operating Revenues1. Revenues from Base Rates -$ 2. Revenues from Surcharges - 3. Other Electric Revenues - 4. Total Electric Operating Revenues -
5. Electric Fuel and Purchased Power Costs - 6. Oper Rev Less Fuel & Purch Pwr Costs -
Other Operating Expenses:7. Operations Excluding Fuel Expense 11,251 8. Maintenance - 9. Subtotal 11,251
10. Depreciation and Amortization - 11. Amortization of Gain - 12. Administrative and General - 13. Other Taxes - 14. Total Other Operating Expense 11,251
15. Operating Income Before Income Tax (11,251)
16. Interest Expense - 17. Taxable Income (11,251)
18. Current Income Tax Rate - 24.75% (2,785)
19. Operating Income (line 15 minus line 18) (8,466)$
(Dollars in Thousands)
Normalize Employee Benefits
Adjustment to Test Year operations to reflect the current December 2018 actuarial valuation of retirement program expenses.
Attachment EAB-9DRPage 1 of 1
ARIZONA PUBLIC SERVICE COMPANYIncome Statement Pro Forma Adjustments
Test Year Ended 6/30/2019
LineNo. Description
Electric Operating Revenues1. Revenues from Base Rates -$ 2. Revenues from Surcharges - 3. Other Electric Revenues - 4. Total Electric Operating Revenues -
5. Electric Fuel and Purchased Power Costs - 6. Oper Rev Less Fuel & Purch Pwr Costs -
Other Operating Expenses:7. Operations Excluding Fuel Expense (8,429) 8. Maintenance - 9. Subtotal (8,429)
10. Depreciation and Amortization - 11. Amortization of Gain - 12. Administrative and General - 13. Other Taxes - 14. Total Other Operating Expense (8,429)
15. Operating Income Before Income Tax 8,429
16. Interest Expense - 17. Taxable Income 8,429
18. Current Income Tax Rate - 24.75% 2,086
19. Operating Income (line 15 minus line 18) 6,343$
(Dollars in Thousands)
Remove Supplemental Excess Benefit Retirement
Plan Expense (SERP)
Adjustment to Test Year operations to remove Supplemental Excess Retirement Plan expense (SERP).
Attachment EAB-10DRPage 1 of 1
ARIZONA PUBLIC SERVICE COMPANYIncome Statement Pro Forma Adjustments
Test Year Ended 06/30/2019
Remove Stock Compensation
LineNo. Description
Electric Operating Revenues1. Revenues from Base Rates -$ 2. Revenues from Surcharges - 3. Other Electric Revenues - 4. Total Electric Operating Revenues -
5. Electric Fuel and Purchased Power Costs - 6. Oper Rev Less Fuel & Purch Pwr Costs -
Other Operating Expenses:7. Operations Excluding Fuel Expense (15,882) 8. Maintenance - 9. Subtotal (15,882)
10. Depreciation and Amortization - 11. Amortization of Gain - 12. Administrative and General - 13. Other Taxes - 14. Total Other Operating Expense (15,882)
15. Operating Income Before Income Tax 15,882
16. Interest Expense - 17. Taxable Income 15,882
18. Current Income Tax Rate - 24.75% 3,931
19. Operating Income (line 15 minus line 18) 11,951$
Adjustment to Test Year operations to remove stock compensation expense.
ARIZONA PUBLIC SERVICE COMPANYIncome Statement Pro Forma Adjustments
Test Year Ended 6/30/2019(Dollars in Thousands)
Attachment EAB-11DRPage 1 of 1
LineNo. Description
Electric Operating Revenues1. Revenues from Base Rates -$ 2. Revenues from Surcharges - 3. Other Electric Revenues - 4. Total Electric Operating Revenues -
5. Electric Fuel and Purchased Power Costs - 6. Oper Rev Less Fuel & Purch Pwr Costs -
Other Operating Expenses:7. Operations Excluding Fuel Expense (3,643) 8. Maintenance - 9. Subtotal (3,643)
10. Depreciation and Amortization - 11. Amortization of Gain - 12. Administrative and General - 13. Other Taxes - 14. Total Other Operating Expense (3,643)
15. Operating Income Before Income Tax 3,643
16. Interest Expense - 17. Taxable Income 3,643
18. Current Income Tax Rate - 24.75% 902
19. Operating Income (line 15 minus line 18) 2,741$
(Dollars in Thousands)
Active Union Medical Trust (VEBA)
Adjustment to Test Year operations to include interest income and realized gain on investments in active union medical trust.
Attachment EAB-12DRPage 1 of 1
ARIZONA PUBLIC SERVICE COMPANYIncome Statement Pro Forma Adjustments
Test Year Ended 6/30/2019
LineNo. Description
Electric Operating Revenues1. Revenues from Base Rates -$ 2. Revenues from Surcharges - 3. Other Electric Revenues - 4. Total Electric Operating Revenues -
5. Electric Fuel and Purchased Power Costs - 6. Oper Rev Less Fuel & Purch Pwr Costs -
Other Operating Expenses:7. Operations Excluding Fuel Expense 4,153 8. Maintenance 126 9. Subtotal 4,279
10. Depreciation and Amortization - 11. Amortization of Gain - 12. Administrative and General 1,327 13. Other Taxes - 14. Total Other Operating Expense 5,606
15. Operating Income Before Income Tax (5,606)
16. Interest Expense - 17. Taxable Income (5,606)
18. Current Income Tax Rate - 24.75% (1,388)
19. Operating Income (line 15 minus line 18) (4,218)$
(Dollars in Thousands)
Normalize Cash Incentive
Adjustment Test Year operations to normalize the cash incentive program over a 3 year period.
Attachment EAB-13DRPage 1 of 1
ARIZONA PUBLIC SERVICE COMPANYIncome Statement Pro Forma Adjustments
Test Year Ended 6/30/2019
LineNo. Description
Electric Operating Revenues1. Revenues from Base Rates -$ 2. Revenues from Surcharges - 3. Other Electric Revenues - 4. Total Electric Operating Revenues -
5. Electric Fuel and Purchased Power Costs - 6. Oper Rev Less Fuel & Purch Pwr Costs -
Other Operating Expenses:7. Operations Excluding Fuel Expense - 8. Maintenance - 9. Subtotal -
10. Depreciation and Amortization - 11. Amortization of Gain - 12. Administrative and General - 13. Other Taxes - 14. Total Other Operating Expense -
15. Operating Income Before Income Tax -
16. Interest Expense 23,665 17. Taxable Income (23,665)
18. Current Income Tax Rate - 24.75% (5,857)
19. Operating Income (line 15 minus line 18) 5,857$
Adjustment to Test Year operations for top down income tax true-ups consistent with Decision Nos. 69663, 71448 and 73183 using the 6/30/2019 rate base and cost of long-term debt. Tax true-ups are reflected as interest in this adjustment.
Attachment EAB-14DRPage 1 of 1
ARIZONA PUBLIC SERVICE COMPANYIncome Statement Pro Forma Adjustments
Test Year Ended 6/30/2019(Dollars in Thousands)
Normalize Income Tax Expense/Interest Synchronization
Annualize PropertyTax Expense
LineNo. Description
Electric Operating Revenues1. Revenues from Base Rates -$ 2. Revenues from Surcharges - 3. Other Electric Revenues - 4. Total Electric Operating Revenues -
5. Electric Fuel and Purchased Power Costs - 6. Oper Rev Less Fuel & Purch Pwr Costs -
Other Operating Expenses:7. Operations Excluding Fuel Expense - 8. Maintenance - 9. Subtotal -
10. Depreciation and Amortization - 11. Amortization of Gain - 12. Administrative and General - 13. Other Taxes 4,549 14. Total 4,549
15. Operating Income Before Income Tax (4,549)
16. Interest Expense - 17. Taxable Income (4,549)
18. Current Income Tax Rate - 24.75% (1,126)
19. Operating Income After Tax (3,423)$
Adjustment to Test Year operations to annualize property taxes calculated using the anticipated 2019 tax assessment ratio and tax rate.
ARIZONA PUBLIC SERVICE COMPANYIncome Statement Pro Forma Adjustments
Test Year Ended 6/30/2019(Dollars in Thousands)
Attachment EAB-15DRPage 1 of 1
LineNo. Description
1. Gross Utility Plant in Service -$
2. Less: Accumulated Depreciation & Amort. -
3. Net Utility Plant in Service -
4. Less: Total Deductions (544)
5. Total Additions (2,198)
6. Total Rate Base (1,654)$
(Dollars in Thousands)
Include Property Tax Deferral
Adjustment to Test Year rate base to include the deferred property tax amounts from July 1, 2019 through December 31, 2020 per ACC Decision No. 76295.
Attachment EAB-16DRPage 1 of 1
ARIZONA PUBLIC SERVICE COMPANYRate Base Pro Forma Adjustments
Test Year Ended 6/30/2019
LineNo. Description
Electric Operating Revenues1. Revenues from Base Rates -$ 2. Revenues from Surcharges - 3. Other Electric Revenues - 4. Total Electric Operating Revenues -
5. Electric Fuel and Purchased Power Costs - 6. Oper Rev Less Fuel & Purch Pwr Costs -
Other Operating Expenses:7. Operations Excluding Fuel Expense - 8. Maintenance - 9. Subtotal -
10. Depreciation and Amortization - 11. Amortization of Gain - 12. Administrative and General - 13. Other Taxes (590) 14. Total Other Operating Expense (590)
15. Operating Income Before Income Tax 590
16. Interest Expense (33) 17. Taxable Income 623
18. Current Income Tax Rate - 24.75% 154
19. Operating Income (line 15 minus line 18) 436$
(Dollars in Thousands)
Amortize Property Tax Deferral
Adjustment to amortize the property tax deferral as authorized in Decision No. 76295 over 10 years.
Attachment EAB-17DRPage 1 of 1
ARIZONA PUBLIC SERVICE COMPANYIncome Statement Pro Forma Adjustments
Test Year Ended 6/30/2019
Annualize Four Corners Power Plant
Coal Reclamation Costs
Line No. Description
Electric Operating Revenues1. Revenues from Base Rates -$ 2. Revenues from Surcharges - 3. Other Electric Revenues - 4. Total Electric Operating Revenues -
5. Electric Fuel and Purchased Power Costs (3,145) 6. Oper Rev Less Fuel & Purch Pwr Costs 3,145
Other Operating Expenses:7. Operations Excluding Fuel Expense - 8. Maintenance - 9. Subtotal -
10. Depreciation and Amortization - 11. Amortization of Gain - 12. Administrative and General - 13. Other Taxes - 14. Total Other Operating Expense -
15. Operating Income Before Income Tax 3,145
16. Interest Expense - 17. Taxable Income 3,145
18. Current Income Tax Rate - 24.75% 778
19. Operating Income (line 15 minus line 18) 2,367$
(Dollars in Thousands)
Adjustment to Test Year operations to reflect the most recent Four Corners Power Plant coal reclamation study.
Attachment EAB-18DRPage 1 of 1
ARIZONA PUBLIC SERVICE COMPANYIncome Statement Pro Forma Adjustments
Test Year Ended 6/30/19
LineNo. Description
Electric Operating Revenues1. Revenues from Base Rates -$ 2. Revenues from Surcharges - 3. Other Electric Revenues - 4. Total Electric Operating Revenues -
5. Electric Fuel and Purchased Power Costs 1,910 6. Oper Rev Less Fuel & Purch Pwr Costs (1,910)
Other Operating Expenses:7. Operations Excluding Fuel Expense - 8. Maintenance - 9. Subtotal -
10. Depreciation and Amortization - 11. Amortization of Gain - 12. Administrative and General - 13. Other Taxes - 14. Total Other Operating Expense -
15. Operating Income Before Income Tax (1,910)
16. Interest Expense - 17. Taxable Income (1,910)
18. Current Income Tax Rate - 24.75% (473)
19. Operating Income (line 15 minus line 18) (1,437)$
(Dollars in Thousands)
Annualize Navajo Power Plant Coal
Reclamation Costs
Adjustment to Test Year operations to reflect the most recent Navajo Power Plant coal reclamation study.
Attachment EAB-19DRPage 1 of 1
ARIZONA PUBLIC SERVICE COMPANYIncome Statement Pro Forma Adjustments
Test Year Ended 6/30/19
LineNo. Description
1. Gross Utility Plant in Service -$
2. Less: Accumulated Depreciation and Amortization -
3. Net Utility Plant in Service -
4. Less: Total Deductions -
5. Total Additions (10,486)
6. Total Rate Base (10,486)$
(Thousands of Dollars)
Adjust Cash Working Capital for Cost of
Service
Adjustment to Cash Working Capital to reflect impacts of cost of service pro formas on the lead/lag study.
Attachment EAB-20DRPage 1 of 1
ARIZONA PUBLIC SERVICE COMPANYPro Forma Adjustments to Original Cost Rate Base
Test Year Ended 6/30/2019
LineNo. Description
Electric Operating Revenues1. Revenues from Base Rates -$ 2. Revenues from Surcharges - 3. Other Electric Revenues - 4. Total Electric Operating Revenues -
5. Electric Fuel and Purchased Power Costs - 6. Oper Rev Less Fuel & Purch Pwr Costs -
Other Operating Expenses:7. Operations Excluding Fuel Expense - 8. Maintenance - 9. Subtotal -
10. Depreciation and Amortization - 11. Amortization of Gain - 12. Administrative and General - 13. Other Taxes - 14. Total Other Operating Expense -
15. Operating Income Before Income Tax -
16. Interest Expense (195) 17. Taxable Income 195
18. Current Income Tax Rate - 24.75% 48
19. Operating Income (line 15 minus line 18) (48)$
(Dollars in Thousands)
Adjust Cash Working Capital for Cost of
Service Pro Formas
Adjustment to Test Year interest expense for cash working capital rate base pro forma adjustment.
Attachment EAB-21DRPage 1 of 1
ARIZONA PUBLIC SERVICE COMPANYIncome Statement Pro Forma Adjustments
Test Year Ended 6/30/2019
LineNo. Description
Electric Operating Revenues1. Revenues from Base Rates -$ 2. Revenues from Surcharges - 3. Other Electric Revenues - 4. Total Electric Operating Revenues -
5. Electric Fuel and Purchased Power Costs - 6. Oper Rev Less Fuel & Purch Pwr Costs -
Other Operating Expenses:7. Operations Excluding Fuel Expense - 8. Maintenance 1,386 9. Subtotal 1,386
10. Depreciation and Amortization - 11. Amortization of Gain - 12. Administrative and General - 13. Other Taxes - 14. Total Other Operating Expense 1,386
15. Operating Income Before Income Tax (1,386)
16. Interest Expense - 17. Taxable Income (1,386)
18. Current Income Tax Rate - 24.75% (343)
19. Operating Income (line 15 minus line 18) (1,043)$
(Dollars in Thousands)
Normalize Nuclear Maintenance Expense
Adjustment to Test Year operations to normalize nuclear production maintenance expense over a 3 year period.
Attachment EAB-22DRPage 1 of 1
ARIZONA PUBLIC SERVICE COMPANYIncome Statement Pro Forma Adjustments
Test Year Ended 6/30/2019
LineNo. Description
Electric Operating Revenues1. Revenues from Base Rates -$ 2. Revenues from Surcharges - 3. Other Electric Revenues - 4. Total Electric Operating Revenues -
5. Electric Fuel and Purchased Power Costs - 6. Oper Rev Less Fuel & Purch Pwr Costs -
Other Operating Expenses:7. Operations Excluding Fuel Expense - 8. Maintenance 5,882 9. Subtotal 5,882
10. Depreciation and Amortization - 11. Amortization of Gain - 12. Administrative and General - 13. Other Taxes - 14. Total Other Operating Expense 5,882
15. Operating Income Before Income Tax (5,882)
16. Interest Expense - 17. Taxable Income (5,882)
18. Current Income Tax Rate - 24.75% (1,456)
19. Operating Income (line 15 minus line 18) (4,426)$
(Dollars in Thousands)
Normalize Fossil Maintenance Expense
Adjustment to Test Year operations to normalize fossil production maintenance expense over a six year period.
Attachment EAB-23DRPage 1 of 1
ARIZONA PUBLIC SERVICE COMPANYIncome Statement Pro Forma Adjustments
Test Year Ended 6/30/19
LineNo. Description
Electric Operating Revenues1. Revenues from Base Rates -$ 2. Revenues from Surcharges - 3. Other Electric Revenues - 4. Total Electric Operating Revenues -
5. Electric Fuel and Purchased Power Costs - 6. Oper Rev Less Fuel & Purch Pwr Costs -
Other Operating Expenses:7. Operations Excluding Fuel Expense - 8. Maintenance 1,487 9. Subtotal 1,487
10. Depreciation and Amortization - 11. Amortization of Gain - 12. Administrative and General - 13. Other Taxes - 14. Total Other Operating Expense 1,487
15. Operating Income Before Income Tax (1,487)
16. Interest Expense - 17. Taxable Income (1,487)
18. Current Income Tax Rate - 24.75% (368)
19. Operating Income (line 15 minus line 18) (1,119)$
Adjust Sundance Maintenance Expense
Adjustment to Test Year operations to annualize the accrual of Sundance maintenance costs as authorized in ACC Decision No. 69663.
Attachment EAB-24DRPage 1 of 1
ARIZONA PUBLIC SERVICE COMPANYIncome Statement Pro Forma Adjustments
Test Year Ended 6/30/19(Dollars in Thousands)
LineNo. Description
Electric Operating Revenues1. Revenues from Base Rates -$ 2. Revenues from Surcharges - 3. Other Electric Revenues - 4. Total Electric Operating Revenues -
5. Electric Fuel and Purchased Power Costs - 6. Oper Rev Less Fuel & Purch Pwr Costs -
Other Operating Expenses:7. Operations Excluding Fuel Expense (10,567) 8. Maintenance (6,446) 9. Subtotal (17,014)
10. Depreciation and Amortization - 11. Amortization of Gain - 12. Administrative and General 541 13. Other Taxes - 14. Total Other Operating Expense (16,473)
15. Operating Income Before Income Tax 16,473
16. Interest Expense - 17. Taxable Income 16,473
18. Current Income Tax Rate - 24.75% 4,077
19. Operating Income (line 15 minus line 18) 12,396$
Attachment EAB-25DR Page 1 of 1
Remove Navajo Power Plant Costs
Adjustment to Test Year operations to remove Navajo O&M and A&G costs as a result of the closure of the Navajo Power Plant.
ARIZONA PUBLIC SERVICE COMPANY
Income Statement Pro Forma AdjustmentsTest Year Ended 6/30/19(Dollars in Thousands)
LineNo. Description
1. Gross Utility Plant in Service -$
2. Less: Accumulated Depreciation and Amortization -
3. Net Utility Plant in Service -
4. Less: Total Deductions 20,395
5. Total Additions 82,403
6. Total Rate Base 62,009$
(Thousands of Dollars)
Include Ocotillo Deferral
Adjustment to Test Year rate base to include the estimated Ocotillo Modernization Project deferral from July 1, 2019 to December 31, 2020 per ACC Decision No.76295.
Attachment EAB-26DRPage 1 of 1
ARIZONA PUBLIC SERVICE COMPANYPro Forma Adjustments to Original Cost Rate Base
Test Year Ended 6/30/19
LineNo. Description
Electric Operating Revenues1. Revenues from Base Rates -$ 2. Revenues from Surcharges - 3. Other Electric Revenues - 4. Total Electric Operating Revenues -
5. Electric Fuel and Purchased Power Costs - 6. Oper Rev Less Fuel & Purch Pwr Costs -
Other Operating Expenses:7. Operations Excluding Fuel Expense - 8. Maintenance - 9. Subtotal -
10. Depreciation and Amortization 9,245 11. Amortization of Gain - 12. Administrative and General - 13. Other Taxes - 14. Total Other Operating Expense 9,245
15. Operating Income Before Income Tax (9,245)
16. Interest Expense - 17. Taxable Income (9,245)
18. Current Income Tax Rate - 24.75% (2,288)
19. Operating Income (line 15 minus line 18) (6,957)$
Attachment EAB-27DRPage 1 of 1
Ocotillo Modernization Project Deferral
Amortization
Adjustment to Test Year operations to include amortization of the Ocotillo Modernization Project deferral.
ARIZONA PUBLIC SERVICE COMPANY
Income Statement Pro Forma AdjustmentsTest Year Ended 6/30/2019
(Dollars in Thousands)
LineNo. Description
Electric Operating Revenues1. Revenues from Base Rates -$ 2. Revenues from Surcharges - 3. Other Electric Revenues - 4. Total Electric Operating Revenues -
5. Electric Fuel and Purchased Power Costs - 6. Oper Rev Less Fuel & Purch Pwr Costs -
Other Operating Expenses:7. Operations Excluding Fuel Expense 5,643 8. Maintenance 1,104 9. Subtotal 6,747
10. Depreciation and Amortization - 11. Amortization of Gain - 12. Administrative and General (16) 13. Other Taxes - 14. Total Other Operating Expense 6,730
15. Operating Income Before Income Tax (6,730)
16. Interest Expense - 17. Taxable Income (6,730)
18. Current Income Tax Rate - 24.75% (1,666)
19. Operating Income (line 15 minus line 18) (5,064)$
Adjustment to Test Year operations to reflect the continuing operations of the Ocotillo Power Plant with the retirement of two steam units and addition of the new units.
ARIZONA PUBLIC SERVICE COMPANY
Income Statement Pro Forma Adjustments
Attachment EAB-28DRPage 1 of 1
Test Year Ended 6/30/19(Dollars in Thousands)
Ocotillo O&M Normalization
Include Four Corners SCR Deferral
LineNo. Description
1. Gross Utility Plant in Service -$
2. Less: Accumulated Depreciation and Amort. -
3. Net Utility Plant in Service -
4. Less: Total Deductions 10,920
5. Total Additions 44,120
6. Total Rate Base 33,200$
Attachment EAB-29DRPage 1 of 1
Adjustment to Test Year rate base to include the estimated Four Corners Selective Catalytic Reduction (SCR) deferral amount from July 1, 2019 to December 31, 2020 per ACC Decision No. 76295.
ARIZONA PUBLIC SERVICE COMPANYPro Forma Adjustments to Original Cost Rate Base
Test Year Ended 6/30/19(Thousands of Dollars)
LineNo. Description
Electric Operating Revenues1. Revenues from Base Rates -$ 2. Revenues from Surcharges - 3. Other Electric Revenues - 4. Total Electric Operating Revenues -
5. Electric Fuel and Purchased Power Costs - 6. Oper Rev Less Fuel & Purch Pwr Costs -
Other Operating Expenses:7. Operations Excluding Fuel Expense - 8. Maintenance - 9. Subtotal -
10. Depreciation and Amortization 8,259 11. Amortization of Gain - 12. Administrative and General - 13. Other Taxes - 14. Total Other Operating Expense 8,259
15. Operating Income Before Income Tax (8,259)
16. Interest Expense - 17. Taxable Income (8,259)
18. Current Income Tax Rate - 24.75% (2,044)
19. Operating Income (line 15 minus line 18) (6,215)$
Attachment EAB-30DRPage 1 of 1
Four Corners SCR Deferral Amortization
Adjustment to Test Year operations to include the amortization of the Four Corners SCR deferral.
ARIZONA PUBLIC SERVICE COMPANY
Income Statement Pro Forma AdjustmentsTest Year Ended 6/30/2019
(Dollars in Thousands)
LineNo. Description
Electric Operating Revenues1. Revenues from Base Rates -$ 2. Revenues from Surcharges - 3. Other Electric Revenues - 4. Total Electric Operating Revenues -
5. Electric Fuel and Purchased Power Costs - 6. Oper Rev Less Fuel & Purch Pwr Costs -
Other Operating Expenses:7. Operations Excluding Fuel Expense - 8. Maintenance - 9. Subtotal -
10. Depreciation and Amortization 1,523 11. Amortization of Gain - 12. Administrative and General - 13. Other Taxes - 14. Total Other Operating Expense 1,523
15. Operating Income Before Income Tax (1,523)
16. Interest Expense - 17. Taxable Income (1,523)
18. Current Income Tax Rate - 24.75% (377)
19. Operating Income (line 15 minus line 18) (1,146)$
Attachment EAB-31DRPage 1 of 1
Cholla Inventory
Adjustment to Test Year operations to reflect the Cholla inventory cost recovery.
ARIZONA PUBLIC SERVICE COMPANYIncome Statement Pro Forma Adjustments
Test Year Ended 6/30/2019(Dollars in Thousands)
LineNo. Description
Electric Operating Revenues1. Revenues from Base Rates -$ 2. Revenues from Surcharges - 3. Other Electric Revenues - 4. Total Electric Operating Revenues -
5. Electric Fuel and Purchased Power Costs - 6. Oper Rev Less Fuel & Purch Pwr Costs -
Other Operating Expenses:7. Operations Excluding Fuel Expense8. Maintenance - 9. Subtotal -
10. Depreciation and Amortization 1,045 11. Amortization of Gain - 12. Administrative and General - 13. Other Taxes - 14. Total Other Operating Expense 1,045
15. Operating Income Before Income Tax (1,045)
16. Interest Expense - 17. Taxable Income (1,045)
18. Current Income Tax Rate - 24.75% (259)
19. Operating Income (line 15 minus line 18) (786)$
Attachment EAB-32DRPage 1 of 1
Four Corners Inventory
Adjustment to Test Year operations to reflect the Cholla inventory cost recovery.
ARIZONA PUBLIC SERVICE COMPANYIncome Statement Pro Forma Adjustments
Test Year Ended 6/30/2019(Dollars in Thousands)
Line
No. DescriptionNormalize Advertising
Electric Operating Revenues1. Revenues from Base Rates -$ 2. Revenues from Surcharges - 3. Other Electric Revenues - 4. Total Electric Operating Revenues -
5. Electric Fuel and Purchased Power Costs - 6. Oper Rev Less Fuel & Purch Pwr Costs -
Other Operating Expenses:7. Operations Excluding Fuel Expense (2,264) 8. Maintenance - 9. Subtotal (2,264)
10. Depreciation and Amortization - 11. Amortization of Gain - 12. Administrative and General - 13. Other Taxes - 14. Total Other Operating Expense (2,264)
15. Operating Income Before Income Tax 2,264
16. Interest Expense - 17. Taxable Income 2,264
18. Current Income Tax Rate - 24.75% 560
19. Operating Income (line 15 minus line 18) 1,704$
(Dollars in Thousands)
Adjustment to Test Year operations to normalize advertising expense over a three-year period.
Attachment EAB-33DRPage 1 of 1
ARIZONA PUBLIC SERVICE COMPANYIncome Statement Pro forma Adjustments
Test Year Ended 6/30/2019
LineWest Phoenix
Removal Costs
No. Description
Electric Operating Revenues -$ 1. Revenues from Base Rates - 2. Revenues from Surcharges - 3. Other Electric Revenues - 4. Total Electric Operating Revenues -
5. Electric Fuel and Purchased Power Costs - 6. Oper Rev Less Fuel & Purch Pwr Costs -
Other Operating Expenses:7. Operations Excluding Fuel Expense - 8. Maintenance - 9. Subtotal -
10. Depreciation and Amortization 998 11. Amortization of Gain - 12. Administrative and General - 13. Other Taxes - 14. Total Other Operating Expense 998
15. Operating Income Before Income Tax (998)
16. Interest Expense - 17. Taxable Income (998)
18. Current Income Tax Rate - 24.75% (247)
19. Operating Income (line 15 minus line 18) (751)$
(Dollars in Thousands)
Adjustment to include the additional removal costs associated with decommissioning West Phoenix Steam Units 4, 5 & 6.
Attachment EAB-34DRPage 1 of 1
ARIZONA PUBLIC SERVICE COMPANYIncome Statement Pro Forma Adjustments
Test Year Ended 06/30/2019
LineNo. Description
Electric Operating Revenues1. Revenues from Base Rates -$ 2. Revenues from Surcharges - 3. Other Electric Revenues - 4. Total Electric Operating Revenues -
5. Electric Fuel and Purchased Power Costs - 6. Oper Rev Less Fuel & Purch Pwr Costs -
Other Operating Expenses:7. Operations Excluding Fuel Expense 3,298 8. Maintenance - 9. Subtotal 3,298
10. Depreciation and Amortization - 11. Amortization of Gain - 12. Administrative and General - 13. Other Taxes - 14. Total Other Operating Expense 3,298
15. Operating Income Before Income Tax (3,298)
16. Interest Expense - 17. Taxable Income (3,298)
18. Current Income Tax Rate - 24.75% (816)
19. Operating Income (line 15 minus line 18) (2,482)$
Attachment EAB-35DRPage 1 of 1
Fire Mitigation
Adjustment to represent forecasted impacts to 2020 O&M as a result of increases to the Fire Mitigation program.
ARIZONA PUBLIC SERVICE COMPANYIncome Statement Pro Forma Adjustments
Test Year Ended 6/30/2019(Dollars in Thousands)
LineNo. Description
Electric Operating Revenues1. Revenues from Base Rates -$ 2. Revenues from Surcharges - 3. Other Electric Revenues - 4. Total Electric Operating Revenues -
5. Electric Fuel and Purchased Power Costs - 6. Oper Rev Less Fuel & Purch Pwr Costs -
Other Operating Expenses:7. Operations Excluding Fuel Expense (17,782) 8. Maintenance - 9. Subtotal (17,782)
10. Depreciation and Amortization - 11. Amortization of Gain - 12. Administrative and General - 13. Other Taxes - 14. Total Other Operating Expense (17,782)
15. Operating Income Before Income Tax 17,782
16. Interest Expense - 17. Taxable Income 17,782
18. Current Income Tax Rate - 24.75% 4,401
19. Operating Income (line 15 minus line 18) 13,381$
Attachment EAB-36DRPage 1 of 1
Customer Affordability
Adjustment to include forecasted impacts to 2020 O&M as a result of the Customer Affordability Program.
ARIZONA PUBLIC SERVICE COMPANYIncome Statement Pro Forma Adjustments
Test Year Ended 6/30/2019(Dollars in Thousands)
LineNo. Description
Electric Operating Revenues1. Revenues from Base Rates -$ 2. Revenues from Surcharges - 3. Other Electric Revenues - 4. Total Electric Operating Revenues -
5. Electric Fuel and Purchased Power Costs - 6. Oper Rev Less Fuel & Purch Pwr Costs -
Other Operating Expenses:7. Operations Excluding Fuel Expense - 8. Maintenance - 9. Subtotal -
10. Depreciation and Amortization - 11. Amortization of Gain - 12. Administrative and General (14,207) 13. Other Taxes - 14. Total Other Operating Expense (14,207)
15. Operating Income Before Income Tax 14,207
16. Interest Expense - 17. Taxable Income 14,207
18. Current Income Tax Rate - 24.75% 3,516
19. Operating Income (line 15 minus line 18) 10,691$
(Dollars in Thousands)
Remove Out of Period and Miscellaneous
Items
Adjustment to Test Year operations to remove out of period and miscellaneous items from the Test Year period.
Attachment EAB-37DRPage 1 of 1
ARIZONA PUBLIC SERVICE COMPANYIncome Statement Pro Forma Adjustments
Test Year Ended 6/30/2019
Cloud Computing
LineNo. Description
1. Gross Utility Plant in Service -$
2. Less: Accumulated Depreciation and Amortization -
3. Net Utility Plant in Service -
4. Less: Total Deductions -
5. Total Additions 12,779
6. Total Rate Base 12,779$
Attachment EAB-38DRPage 1 of 1
Adjustment to increase to Test Year rate base to reflect the impacts of Cloud Computing consistent with NARUC's Cloud Computing Resolution.
ARIZONA PUBLIC SERVICE COMPANYPro Forma Adjustments to Original Cost Rate Base
Test Year Ended 6/30/2019(Thousands of Dollars)
LineNo. Description
1. Gross Utility Plant in Service -$
2. Less: Accumulated Depreciation and Amortization -
3. Net Utility Plant in Service -
4. Less: Total Deductions (90,705)
5. Total Additions -
6. Total Rate Base 90,705$
Attachment EAB-39DRPage 1 of 1
Excess Deferred Tax
Adjustment to Rate Base to reflect amortization of excess deferred taxes associated with TEAM III between Test Year and estimated rate effective date. This pro forma assumes TEAM III amortization will begin January 1, 2020 and rates will become effective January 1, 2021.
ARIZONA PUBLIC SERVICE COMPANYPro Forma Adjustments to Original Cost Rate Base
Test Year Ended 6/30/2019(Thousands of Dollars)
LineNo. Description
Electric Operating Revenues1. Revenues from Base Rates -$ 2. Revenues from Surcharges - 3. Other Electric Revenues - 4. Total Electric Operating Revenues -
5. Electric Fuel and Purchased Power Costs - 6. Oper Rev Less Fuel & Purch Pwr Costs -
Other Operating Expenses:7. Operations Excluding Fuel Expense - 8. Maintenance - 9. Subtotal -
10. Depreciation and Amortization (11,504) 11. Amortization of Gain - 12. Administrative and General - 13. Other Taxes - 14. Total Other Operating Expense (11,504)
15. Operating Income Before Income Tax 11,504
16. Interest Expense - 17. Taxable Income 11,504
18. Current Income Tax Rate - 24.75% 2,847
19. Operating Income (line 15 minus line 18) 8,657$
Attachment EAB-40DRPage 1 of 1
Cholla Unit 2 Regulatory Asset Amortization
Adjustment to Test Year operations to amortize Cholla Unit 2 Regulatory Asset over the remaining plant life instead of the accelerated method approved in Decision No. 76295.
ARIZONA PUBLIC SERVICE COMPANYIncome Statement Pro Forma Adjustments
Test Year Ended 6/30/2019(Dollars in Thousands)
