"Quarterly Review"
Selected Financial and Operational Data:
Re:
Electric Companies
● Duke Energy Carolinas, LLC
● Duke Energy Progress, LLC,
d/b/a Duke Energy Progress
● Virginia Electric and Power Company,
d/b/a Dominion North Carolina Power
Natural Gas Local Distribution Companies
● Piedmont Natural Gas Company, Inc.
● Public Service Company of North Carolina, Inc.,
d/b/a PSNC Energy
■ Quarter Ending June 30, 2015 ■
Prepared by:
North Carolina Utilities Commission
Operations Division
430 N. Salisbury Street Mailing Address:
Raleigh, NC 27603 4325 Mail Service Center
919-733-3979 www.ncuc.net Raleigh, NC 27699-4300
~ tah~ of~ ort4 Qlarolina
~til iti£s Qlommission
4325 Mail Service Center
Raleigh, NC 27699-4325
COMMISSIONERS
EDWARDS. FINLEY, JR, CHAIRMAN
BRYAN E. BEATTY
SUSAN W. RABON October 8, 2015
MEMORANDUM
TO:
FROM:
Chairman Edward S. Finley, Jr.
Commissioner Bryan E. Beatty
Commissioner Susan W. Rabon
Commissioner ToNola D. Brown-Bland
Commissioner Don M. Bailey
Commissioner Jerry C. Dockham
Commissioner James G. Patterson
Donald R. Hoover, Director 'JJilll
Operations Division
COMMISSIONERS
TONOLA D. BROWN-BLAND
DON M. BAILEY
JERRY C. DOCKHAM
JAMES G. PATTERSON
The Operations Division hereby presents for your consideration the Quarterly Review
for the calendar quarter ending June 30, 2015. Such report, which has been prepared
by the Operations Division, presents an overview of selected financial and operational
information and data for five major investor-owned public utilities regulated by the
Commission.
Should you have questions concerning the report, Freda Hilburn, Bliss Kite, or I will be
pleased to be of assistance.
Thank you for your consideration.
DRH/FHH/BBK!jme
430 North Salisbury Street • Raleigh, North Carolina 27603
Telephone No: (919) 733-4249
Facsimile No: (919) 733-7300
www. neue. net
iii
Table of Contents
Part Page
I Introduction
1
II Review of Key Financial Ratios: 9
◘ Summary Statement of Key Financial Ratios For Five Selected
Companies For The Twelve Months Ended June 30, 2015 –
Returns on Common Equity, Overall Rates of Return, Common
Equity Capitalization Ratios, And Debt Ratios – And Certain
Rate Case Data
10
◘ Statement of Authorized Returns on Common Equity and
Overall Rates of Return Granted By Various Public Utility
Regulatory Agencies As Reported By Public Utilities Reports,
Volume Nos. 309-320, from December 2013 Through
May 2015.
12
III Overviews of Selected Financial and Operational Data By Utility: 14
◘ Electric Companies:
 Duke Energy Carolinas, LLC
15
 Duke Energy Progress, LLC, d/b/a
Duke Energy Progress
16
 Virginia Electric and Power Company, d/b/a
Dominion North Carolina Power
17
◘ Natural Gas Local Distribution Companies:
 Piedmont Natural Gas Company, Inc.
18
 Public Service Company of North Carolina, Inc., d/b/a
PSNC Energy
19
IV Telecommunications Companies – Annual Report Filings 20
V Appendix A – Electronic Distribution List
Part I
Introduction
◘ The purpose, structure, focus, and an abbreviated synopsis of the
nature of the contents of this report is presented here.
2
The Quarterly Review has been designed and is structured so as to provide, in a
clear and concise format, relevant and useful financial and operational information
pertaining to five major investor-owned public utilities regulated by the North Carolina
Utilities Commission (Commission): three electric companies and two natural gas local
distribution companies. The primary focus of this report is one of a jurisdictional financial
nature. However, albeit limited, certain jurisdictional operational information is also
included.
To a vast extent the information presented herein is organized into individual
company overviews and covers a period of five years. From a general viewpoint, the
individual company overviews provide information that users of this report will find helpful
from the standpoint of gaining insight into each company's jurisdictional financial standing
and in acquiring a sense of the magnitude of each company's overall jurisdictional
economic dimension.
As reported previously, significant changes took place with regard to the annual
reporting requirements for the price plan regulated telephone companies since the
12-month reporting period ending December 31, 2010. Specifically, on June 30, 2011, in
Docket No. P-100, Sub 72b, the Commission issued an Order ruling on a petition filed by
the North Carolina Telecommunications Industry Association, Inc. on March 16, 2011,
requesting modification or elimination of certain reporting requirements relating to
incumbent local exchange companies (ILECs) and/or competing local providers (CLPs).
The June 30, 2011 Order, among other things, revised Commission Rule R1-32 by adding
a new Subsection (e1). Such revision allows ILECs, that are price plan regulated under
G.S. 62-133.5(a), and any carrier electing regulation under G.S. 62-133.5(h) to satisfy all of
their annual reporting obligations by one of the two following ways: (1) by providing a link to
their annual filings with the Securities and Exchange Commission (SEC), if they are
publicly traded entities, or (2) by filing copies of their audited financial statements with the
Commission, if they are not publicly traded entities. By Order dated November 22, 2011, in
Docket No. P-100, Sub 165A, the Commission applied this same rule to entities operating
under G.S. 62-133.5(m). The foregoing would be in lieu of filing annual reports regarding
the North Carolina Operations on forms furnished or approved by the Commission. Price
plan regulated telephone companies are required to either provide their annual reports to
the Commission or otherwise satisfy their annual reporting obligations under Commission
Rule R1-32, Subsection (e1) as soon as possible after the close of the calendar year, but
in no event later than the 30th day of April each year for the preceding calendar year.
The majority of the price plan regulated telephone companies have elected to meet
their annual reporting obligation by providing links to their annual filings with the SEC. For
the following ILECs: (1) BellSouth Telecommunications, LLC, d/b/a AT&T North Carolina
(AT&T North Carolina); (2) Carolina Telephone and Telegraph Company LLC, d/b/a
CenturyLink (Carolina); (3) Central Telephone Company, d/b/a CenturyLink (Central);
(4) Mebtel, Inc., d/b/a CenturyLink (Mebtel); (5) Frontier Communications of the Carolinas
3
Inc. (Frontier); (6) Verizon South Inc. (Verizon South); (7) Windstream Concord Telephone,
Inc. (Concord); (8) Windstream Lexcom Communications, Inc. (Lexcom); and
(9) Windstream North Carolina, LLC (Windstream NC) the url addresses/links to their
2014 annual filings with the SEC are provided in this report in Part IV.
With respect to other changes related to matters concerning the price plan regulated
telephone companies, on June 30, 2009, House Bill 1180 (HB 1180) became law as set
forth in Session Law 2009-238. Said law, entitled “An Act Establishing the Consumer
Choice and Investment Act of 2009,” created a new category of price plan operation
whereby any ILEC or CLP may choose to adopt such a plan by simply “filing notice of its
intent to do so with the Commission,” with such election being effective immediately upon
filing. Subsection (h) price plans1 provide for extensive deregulation of an electing
telecommunications company’s “terms, conditions, rates, or availability” relating to its retail
services. An ILEC electing Subsection (h) is required to continue to offer stand-alone basic
residential lines to all customers who choose to subscribe to that service at rates that can
be increased annually by no more than the percentage increase over the prior year in the
Gross Domestic Product Price Index (GDP-PI). While such deregulation is very extensive
by historical standards, it is not a complete deregulation of carriers electing
Subsection (h).2
Currently, there are eight ILECs operating under Subsection (h) price plans as a
result of their notices of election filed pursuant to G.S. 62-133.5(h): (1) Verizon South3
(notice filed on July 21, 2010 to become effective immediately, in Docket No. P-19,
Sub 277M); (2) Frontier (notice filed January 30, 2012 to become effective immediately, in
Docket No. P-1488, Sub 1A); (3) Concord (notice filed July 26, 2012 to become effective
immediately, in Docket No. P-16, Sub 181L); (4) Lexcom (notice filed July 26, 2012 to
become effective immediately, in Docket No. P-31, Sub 145C); (5) Windstream NC (notice
filed July 26, 2012 to become effective immediately, in Docket No. P-118, Sub 86L);
(6) North State Telephone Company, d/b/a North State Communications (North State)
(notice filed November 30, 2012 to become effective immediately, in Docket No. P-42,
Sub 137F); (7) Ellerbe Telephone Company (Ellerbe) (notice filed December 30, 2013 to
become effective January 1, 2014, in Docket No. P-21, Sub 75); and (8) Town of Pineville,
d/b/a Pineville Telephone Company (Pineville) (notice filed July 1, 2014 to become
effective immediately in Docket No. P-120, Sub 27).
Furthermore, on April 26, 2011, Senate Bill 343 (SB 343) became law as set forth in
Session Law 2011-52. Said law, entitled “An Act Establishing the Communications Reform
1 In general, the Commission refers to the new price plan category which resulted from the passage of
HB 1180 as “Subsection (h) price plans”.
2 See Docket No. P-100, Sub 165 for additional information regarding the implications of the enactment of
HB 1180 and the implementation of Subsection (h) price plans.
3 Such election relates to Verizon South’s only exchange, the Knotts Island exchange.
4
and Investment Act of 2011”, created a new category of price plan operation outlined in
G.S. 62-133.5(m)4 whereby any local exchange company that forgoes receipt of any
funding from a state universal service fund or alternative funding mechanism that may be
established to support universal service as described in G.S. 62-110(f1) and whose
territory is open to competition from CLPs may choose to adopt a Subsection (m) price
plan5 by simply “filing notice of its intent to do so with the Commission,” with such election
being effective immediately upon filing. Subsection (m) price plans provide, among other
things, that “the Commission shall not impose any requirements related to the terms,
conditions, rates, or availability of any of the local exchange company’s retail services.”6
Currently, there are four ILECs operating under Subsection (m) price plans as a
result of their notices of election filed pursuant to G.S. 62-133.5(m): (1) AT&T North
Carolina (notice filed October 14, 2011, to become effective immediately, in Docket
No. P-55, Sub 1013M); (2) Carolina (notice filed October 31, 2014 to become effective
November 1, 2014, in Docket No. P-7, Sub 825N); (3) Central (notice filed
October 31, 2014 to become effective November 1, 2014, in Docket No. P-10, Sub 479O);
and (4) Mebtel (notice filed October 31, 2014 to become effective November 1, 2014, in
Docket No. P-35, Sub 96J). Prior to such elections, these entities were operating under
Subsection (h) price plans.7
As a result of their Subsection (h) elections (and continuing with any subsequent
Subsection (m) elections), the 12 ILECs discussed hereinabove are no longer required to
provide annual reports with the Commission as directed by Commission Rule R1-32,
commencing with the calendar year in which the Subsection (h) election became effective
(2009: AT&T North Carolina; 2010: Verizon South; 2012: Frontier, Carolina, Central,
Mebtel, Concord, Lexcom, Windstream NC, and North State; and 2014: Ellerbe and
Pineville). Alternatively, as required by the Commission’s March 30, 2010 Order in Docket
No. P-100, Sub 165, and the November 22, 2011 Order in Docket No. P-100, Sub 165A,
4 The enabling legislation was initially specified in G.S. 62-133.5(l); however, such reference has been
renumbered and codified in the General Statutes of North Carolina as G.S. 62-133.5(m). Consequently, on
April 27, 2012, the Commission issued an Errata Order to correct the reference of Subsection (l) in prior
Commission orders to Subsection (m) for consistency with the codification in the General Statutes.
5 In general, the Commission refers to the new price plan category which resulted from the passage of SB 343
as “Subsection (m) price plans”.
6 Such retail services include stand-alone basic residential lines. See Docket No. P-100, Sub 165A for
additional information regarding the implications of the enactment of SB 343 and the implementation of
Subsection (m) price plans.
7 On October 5, 2009, in Docket No. P-55, Sub 1013M, AT&T North Carolina filed its notice of election of a
Subsection (h) price plan. On March 8, 2012, in Docket Nos. P-7, Sub 825M, P-10, Sub 479N, and P-35,
Sub 96I, Carolina, Central, and Mebtel, respectively, filed their notices of election of a Subsection (h) price
plan.
5
these ILECs will provide the Commission, on an annual basis, a link to their financial filings
with the SEC.
This report has been prepared solely for the use of the Commission. The
responsibility for developing and preparing the report is that of the Commission's
Operations Division. The preponderance of the information and data included in and/or on
which the report is based has been provided by the companies. Such data has not been
audited or otherwise verified. Therefore, the Operations Division, although it believes the
aforesaid data to be true and correct in each and every respect, cannot and does not offer
any attestation in that regard.
A Specific Objective
A specific objective of this reporting process is to present to the Commission, on an
ongoing basis, meaningful information regarding the financial viability of the subject
companies, including the reasonableness of the overall levels of rates and charges
currently being charged by jurisdictional utilities, whose rates are cost based, for their sales
of services. Cost based regulation is synonymous with rate base, rate of return regulation.
Under rate base, rate of return regulation, the cost of service of a public utility is
defined as the sum total of reasonable operating expenses, depreciation, taxes, and a
reasonable return on the net valuation of property used and useful in providing public utility
services. Therefore, the reasonableness of a public utility's rates is a function of the
reasonableness of the level of each individual component of its cost of service.
The reasonable return component of the cost of service equation refers to the
overall rate of return related to investment funded by all investors, including debt investors
as well as preferred and common equity investors.8 The costs of debt capital and preferred
stock, which are essentially fixed by contract, must be deducted from revenue, like all other
components of the cost of service, in determining income available for distribution to
common stockholders. Therefore, generally speaking, a very meaningful measure of the
profitability of any utility, and consequently the reasonableness of its overall rates and
charges, is the return earned on its common shareholders' investment, i.e., its return on
common equity, over some specified period of time. Typically, such returns are measured
over a period of one year. Thus, annual returns on common equity and certain other key
financial ratios, which among other things give significant perspective to the common equity
returns, are the focal points of this report.
8 Regarding Limited Liability Corporations (LLCs), equity investors are, typically, referred to as “members”
rather than as “shareholders or stockholders”. Consequently, references to “common
shareholders/stockholders”, as contained herein, are also intended to apply to equity investors of LLCs as
well. Additionally, discussion regarding “return on common equity” and the “common equity capitalization ratio”
would also apply to the LLC’s “return on members’ equity” and “members’ equity capitalization ratio”.
6
The Key Financial Ratios
Specifically, the key financial ratios presented herein for use in reviewing the
companies' financial viabilities, including their profitability and consequently the
reasonableness of their rates and charges are (1) the return on common equity, (2) the
common equity capitalization ratio, (3) the pretax interest coverage ratio, and (4) the overall
rate of return.
The Return on Common Equity
As indicated, the return on common equity is a key financial indicator which
measures the profitability of an enterprise from the standpoint of its common stockholders
over some specified period of time. That return or earnings rate reflects the ratio of
earnings available for common equity to the common-equity investors' capital investment.
As previously stated, the ratio is significant because it traditionally represents profitability
after all revenues and costs, other than the cost of common equity capital, have been
considered. From the standpoint of measuring profitability, return on common equity is
indeed "the bottom line".
The Common Equity Capitalization Ratio
The common equity capitalization ratio is the ratio of common equity capital to total
investor-supplied capital of the firm. That ratio is significant because it is a major indicator
of the financial riskiness of the firm, particularly from the standpoint of the common
stockholders. The issuance of debt capital, assuming no offsetting decrease in preferred
stock, decreases the common equity capitalization ratio, and its existence creates what has
come to be known as financial leverage. The risk borne by shareholders that accompanies
that leverage is known as financial risk. As the proportion of debt in the capital structure
increases, so does the degree of financial leverage and thus shareholders' risk and
consequently the shareholders' requirements regarding expected return, i.e., the expected
return on common equity or, in regulatory jargon, the cost of common equity capital.
Alternatively, the financial riskiness of the firm, some might argue, is more
appropriately revealed when expressed in terms of debt leverage, particularly when
preferred stock is present in the capital structure. Such leverage is the ratio of long-term
debt capital to total investor-supplied capital. Both approaches are clearly insightful and
useful. In evaluating the superiority of one approach in comparison to the other, one should
consider the context within which the information is to be used. Since a major objective of
this report is to review the reasonableness of the levels of earnings of the companies'
common stockholders, and in consideration of the other key financial benchmarks which
are also presented herein, the common equity capitalization ratio appears to be the most
appropriate and meaningful measure of the financial riskiness of the companies for use in
this regard.
7
The Pretax Interest Coverage Ratio
The pretax interest coverage ratio is the number of times earnings, determined
before consideration of income taxes and interest charges, cover annual interest charges.
That financial indicator is particularly important to debt investors because holders of the
company's outstanding debt, including long-term bonds, receive interest payments from the
company before any earnings are determined to be available for distribution to preferred or
common equity investors. Pretax interest coverage is measured before income taxes
because interest expense is deductible in arriving at taxable income. Therefore, generally
speaking, debt holders can expect to be paid before the company incurs any liability for the
payment of income taxes. From the debt holder's perspective, all other things remaining
equal, the higher the pretax interest coverage the better.
The Overall Rate of Return
The overall rate of return measures the profitability of a firm from the standpoint of
earnings on total investment, including investment funded by both debt and equity
investors. Specifically, in the public utility regulatory environment, it is the ratio of operating
income to total investment.
The Propriety of the Methodology
The foregoing financial benchmarks, as presented in this report, have been
determined on the basis of the companies' actual operating experience. Under rate base,
rate of return regulation, North Carolina statutes require that the companies' rates be
determined on a normalized, pro forma, end-of-period basis based upon an historical test
period. Stated alternatively, the Commission, in setting prospective rates, essentially, must
take into account the company's current level of operations adjusted for known and
material changes in the levels of revenues and costs that the company can reasonably be
expected to experience over a reasonable period of time into the future. Thus, rates, which
are established for use prospectively, are set, to a certain extent and within certain
constraints, on the basis of revenue and cost expectations, including investor expectations
regarding their return requirements, as opposed to simply setting prospective rates solely
on the basis of actual operating experience.
The process of setting prospective rates is inherently and exceedingly time
consuming, difficult, and otherwise costly to both companies and regulators. It involves the
assimilation, investigation, and evaluation of enormous amounts of complex information
and data which invariably leads to multifarious issues; many, if not most, of which must be
resolved through adjudication.
It is far less difficult and costly to perform an intellectual, financial analysis of the
need to undertake the aforesaid process. Such preliminary analysis avoids the
unnecessary incursion of the immense costs of setting prospective rates. Those are
8
precisely the reasons why this report is focused on a review of the returns on common
equity and other key financial ratios which the companies are currently earning or achieving
under their existing rates and charges. Those ratios, when considered in conjunction with
statutory ratemaking requirements, prevailing economic conditions, and certain other
financial indicators, including returns on common equity and overall rates of return currently
being authorized by other public utility regulatory agencies, are meaningful indicators of the
need, if any, for further, more extensive regulatory review.
From the standpoint of giving an added measure of meaning to the aforesaid ratios
of the individual companies and in the interest of providing a sense of current financial
market conditions, certain financial information has been included herein as notes to the
first statement included in Part II of this report. Such notes are an integral part of this
report.
Additionally, also from the standpoint of providing perspective, returns on common
equity and overall rates of return currently being authorized by a number of other public
utility regulatory agencies are provided in the second statement presented in Part II.
A Final Note
It is emphasized that the information contained in this report is not intended and
should not be construed to be all inclusive from the standpoint of the criteria to be used in
assessing the reasonableness of the companies’ existing rates. But rather, it is submitted
that such information is clearly relevant to such a determination and as such should be
considered in conjunction with all other pertinent information and data.
The Operations Division will be pleased to receive and respond to any questions or
comments.
Part II
A Review of Key Financial Ratios
◘ Summary Statement of Key Financial Ratios For
Five Selected Companies For The Twelve Months
Ended June 30, 2015 ─ Returns on Common
Equity, Overall Rates of Return, Common Equity
Capitalization Ratios, and Debt Ratios ─ And
Certain Rate Case Data
◘ Statement of Authorized Returns on Common
Equity and Overall Rates of Return Granted By
Various Public Utility Regulatory Agencies As
Reported By Public Utilities Reports, Volume
Nos. 309-320 from December 2013 Through
May 2015
Return Overall Return Overall Date of
Line On Rate of Equity Debt On Rate of Equity Last
No. Item Equity Return Ratio Ratio Equity Return Ratio Order
(a) (b) (c) (d) (e) (f) (g) (h) (i)
Electric Companies
1. Duke Energy Carolinas, LLC 10.83% 8.27% 56.38% 43.62% 10.20% 7.88% 53.00% 09/24/2013
2. Duke Energy Progress, LLC 9.82% 7.18% 52.21% 47.79% 10.20% 7.55% 53.00% 05/30/2013
d/b/a Duke Energy Progress
3. Virginia Electric and Power Company, 7.69% 6.30% 53.04% 46.75% 10.20% 7.80% 51.00% 12/21/2012
d/b/a Dominion North Carolina Power
Natural Gas Local Distribution Companies
4. Piedmont Natural Gas Company, Inc. 8.85% 6.12% 43.83% 56.17% 10.00% 7.51% 50.66% 12/17/2013
5. Public Service Company of North Carolina, Inc., 10.32% 8.48% 59.29% 40.71% 10.60% 8.54% 54.00% 10/24/2008
d/b/a PSNC Energy
10
Estimated for 12 Months Ended 06/30/2015
Common Equity Capitalization Ratios, and Debt Ratios are for Twelve Months Ended June 30, 2015
"Rate Case Data are from Orders with Various Issue Dates as Indicated in Column (i)"
Summary Statement
Of Key Financial Ratios Achieved By
And Authorized For Selected Companies
"Estimated Returns on Common Equity, Overall Rates of Return,
Authorized - Last Rate Case
Summary Statement
Of Key Financial Ratios Achieved by
And Authorized for Selected Companies
“Estimated Returns on Common Equity, Overall Rates of Return,
Common Equity Capitalization Ratios, and Debt Ratios are for Twelve Months Ended June 30, 2015”
NOTES: [1] Selected financial market indicators from “Moody’s Credit Trends” updated on September 25, 2015 follow:
Part I
________U.S. Treasury Securities________ Dealer-
Placed
Moody’s
Long-Term
3-Month
Bill
10-Year
Note
30-Year
Bond
3-Month
CP
Corporate
Bond Yield
Line No. Date % % % % %
(a) (b) (c) (d) (e) (f)
1. September 24, 2015 0.01 2.13 2.91 0.19 4.53
2. September 23, 2015 0.01 2.16 2.95 0.20 4.56
3. September 22, 2015 (0.01) 2.14 2.94 0.18 4.55
4. September 21, 2015 0.01 2.20 3.02 n/a 4.65
5. September 18, 2015 (0.01) 2.13 2.93 n/a 4.54
6. Month of August 2015 0.06 2.17 2.86 n/a n/a
7. Month of July 2015 0.03 2.33 3.07 n/a n/a
Part II
Moody’s public utilities long-term bond yield averages (%):
_Past 12 Months_ Monthly Average
Line No. Rating 9/24/2015 High Low Sep. 2015 Aug. 2015
(a) (b) (c) (d) (e) (f)
1. Aa 4.17 4.29 3.52 4.27 4.13
2. A 4.34 4.40 3.58 4.40 4.25
3. Baa 5.38 5.42 4.39 5.42 5.23
[2] Most recent data available when this edition of the Quarterly Review was prepared. According to “Moody’s Credit
Trends”, updated on September 25, 2015, such long-term bond yield averages are derived from pricing data on a
regularly-replenished population of nearly 90 seasoned corporate bonds in the United States market, each with
current outstandings over $100 million. Further, the bonds have maturities as close as possible to 30 years; bonds
are dropped from the list if their remaining life falls below 20 years or if their ratings change.
11
Authorized Returns Volume No.
Line Common Date Of Public Utilities
No. Company (Jurisdiction) Equity Overall Order Reports
(a) (b) (c) (d) (e)
.
Electric Companies
1. Southwestern Electric Power Company (TX) 9.65% 7.77% 10/10/2013 Volume 309
2. Westar Energy, Inc. (KS) N/A N/A 11/21/2013 Volume 309
3. Virginia Electric and Power Company (VA) 10.00% N/A 11/26/2013 Volume 309
4. Baltimore Gas and Electric Company (MD) 9.75% N/A 12/13/2013 Volume 311
5. Northern States Power Company (ND) 9.75% [1] N/A 02/26/2014 Volume 312
6. Potomac Electric Power Company (DC) 9.40% 7.65% 03/26/2014 Volume 313
7. Potomac Electric Power Company (MD) 9.62% 7.61% 07/02/2014 Volume 314
8. Kansas City Power & Light Company (KS) N/A N/A 07/17/2014 Volume 315
9. Rockland Electric Company (NJ) 9.75% 7.83% 07/23/2014 Volume 315
10. Delmarva Power & Light Company (DE) 9.70% 7.26% 08/05/2014 Volume 315
11. Ameren Illinois Company, d/b/a Ameren Illinois (IL) 9.25% 8.075% 12/10/2014 Volume 317
12. Connecticut Light & Power Company (CT) 9.17% 7.31% 12/17/2014 Volume 318
13. Rocky Mountain Power (WY) 9.50% 7.41% 01/23/2015 Volume 319
14. Pacific Power & Light Company, 9.50% 7.30% 03/26/2015 Volume 320
a division of PacifiCorp (WA)
15. Union Electric Company, d/b/a 9.53% N/A 04/29/2015 Volume 320
Ameren Missouri (MO)
16. Northern States Power Company (MN) 9.72% 7.35% 05/08/2015 Volume 320
Natural Gas Local Distribution
Companies
17. Duke Energy Ohio, Inc. (OH) 9.84% 7.73% 11/13/2013 Volume 309
18. Connecticut Natural Gas Corporation (CT) 9.18% 7.88% 01/22/2014 Volume 310
19. Baltimore Gas and Electric Company (MD) 9.60% N/A 12/13/2013 Volume 311
20. Northern Utilities, Inc., d/b/a Unitil (ME) N/A 8.40% 12/27/2013 Volume 311
21. Questar Gas Company (UT) 9.85% 7.64% 02/21/2014 Volume 312
22. Arkansas Oklahoma Gas Corporation (AR) 9.30% 6.18% 07/25/2014 Volume 314
23. Indiana Natural Gas Corporation (IN) 10.10% 9.47% 07/30/2014 Volume 314
12
Statement of Authorized Returns
On Common Equity and Overall Rates of Return
Granted By Various Public Utility Regulatory Agencies As Reported In
(Statement Is All Inclusive With Respect To Returns Published)
Public Utilities Reports, Volume Nos. 309-320, from December 2013 through May 2015
Volume No.
Line Common Date Of Public Utilities
No. Company (Jurisdiction) Equity Overall Order Reports
(a) (b) (c) (d) (e)
Natural Gas Local Distribution
Companies (continued)
24. Centerpoint Energy Resources Corporation, d/b/a 9.59% 7.42% 06/09/2014 Volume 315
Centerpoint Energy Minnesota Gas (MN)
25. Centerpoint Energy Resources Corporation, d/b/a 10.50% N/A 07/03/2014 Volume 316
Centerpoint Energy Oklahoma Gas (OK)
26. Cheyenne Light, Fuel, and Power Company (WY) 9.90% 7.98% 09/29/2014 Volume 317
27. Minnesota Energy Resources Corporation (MN) 9.35% 7.30% 10/28/2014 Volume 317
28. Summit Natural Gas of Missouri, Inc. (MO) 10.80% 7.54% 10/29/2014 Volume 317
29. Liberty Utilities (Midstates Natural Gas) Corporation, 9.76% 7.05% 02/11/2015 Volume 319
d/b/a Liberty Utilities (IL)
30. Questar Gas Company (WY) 9.50% 7.51% 03/02/2015 Volume 320
Water Companies
31. Iowa-American Water Company (IA) 9.90% N/A 02/28/2014 Volume 312
32. United Water New York, Inc. (NY) 9.00% [2] 6.80% 06/26/2014 Volume 314
33. Water Service Corporation of Kentucky (KY) N/A N/A 07/24/2014 Volume 314
34. San Jose Water Company (CA) N/A 8.09% 08/14/2014 Volume 315
Notes:
[1] The North Dakota Public Service Commission approved a settlement agreement that establishes, among other things, a multi-year
rate plan that allows for an authorized ROE of 9.75% in 2013, 10.00% in 2014, 10.00% in 2015, and 10.25% in 2016. The utility is
required to refund 50% of any earnings above the authorized ROE during the term of the rate plan.
[2] In its June 26, 2014 Order, the New York Public Service Commission authorized that United Water New York, Inc. may elect a two-year
levelized stayout alternative that allows for a return on common equity of 9.20%.
[3] N/A denotes that information is not available.
13
Authorized Returns
Public Utilities Reports, Volume Nos. 309-320, from December 2013 through May 2015
(Statement Is All Inclusive With Respect To Returns Published)
Statement of Authorized Returns
On Common Equity and Overall Rates of Return
Granted By Various Public Utility Regulatory Agencies As Reported In
Part III
Overviews of Selected
Financial and Operational Data by Utility:
◘ Electric Companies
▪ Duke Energy Carolinas, LLC
▪ Duke Energy Progress, LLC,
d/b/a Duke Energy Progress
▪ Virginia Electric and Power Company,
d/b/a Dominion North Carolina Power
◘ Natural Gas Local Distribution Companies
▪ Piedmont Natural Gas Company, Inc.
▪ Public Service Company of North Carolina, Inc.
d/b/a PSNC Energy
Annual
Line June June June June June Four Current
No. Item 2015 2014 2013 2012 2011 Year Year
(a) (b) (c) (d) (e) (f) (g) (h)
1. Operating Revenue $4,957,515 $5,151,782 $4,825,878 $4,483,069 $4,496,774 2.47% -3.77%
2. Operating Expenses:
3. Fuel 1,079,234 1,241,218 1,132,152 994,635 1,191,452 -2.44% -13.05%
4. Purchased Power 252,800 213,456 214,622 221,585 187,825 7.71% 18.43%
5. Maintenance 465,404 393,349 452,187 423,835 423,962 2.36% 18.32%
6. Other Operating Expenses 845,124 898,909 962,535 818,833 911,099 -1.86% -5.98%
7. Total Operating Expenses 2,642,562 2,746,932 2,761,496 2,458,888 2,714,338 -0.67% -3.80%
8. Depreciation & Amortization 751,645 715,366 642,024 596,404 522,756 9.50% 5.07%
9. Total Expenses & Depreciation 3,394,207 3,462,298 3,403,520 3,055,292 3,237,094 1.19% -1.97%
10. Total Operating Taxes 567,300 737,728 621,911 638,084 569,266 -0.09% -23.10%
11. Total Expenses, Depr. & Taxes 3,961,507 4,200,026 4,025,431 3,693,376 3,806,360 1.00% -5.68%
12. Operating Income $996,008 $951,756 $800,447 $789,693 $690,414 9.59% 4.65%
13. Net Plant Investment $14,897,815 $13,504,366 $14,675,521 $12,430,597 $11,191,021 7.41% 10.32%
14. Oper. Exp. as a % of Total Revenue 53.30% 53.32% 57.22% 54.85% 60.36% -3.06% -0.04%
15. Net Plt. Investment per $ of Revenue $3.01 $2.62 $3.04 $2.77 $2.49 4.86% 14.89%
16. Number of Customers Served (000s included):
17. Residential 1,644,343 1,620,633 1,606,623 1,596,272 1,587,075 0.89% 1.46%
18. Commercial 258,067 255,489 253,543 252,301 250,588 0.74% 1.01%
19. Industrial 4,801 4,886 4,950 5,045 5,226 -2.10% -1.74%
20. Other 11,564 11,097 11,007 10,889 10,937 1.40% 4.21%
21. Total Number of Customers 1,918,775 1,892,105 1,876,123 1,864,507 1,853,826 0.86% 1.41%
22. Annual Sales Volume: (Millions kWh)
23. Residential 21,230 21,246 20,888 20,362 22,411 -1.34% -0.08%
24. Commercial 22,784 22,527 22,044 21,819 22,092 0.77% 1.14%
25. Industrial 12,987 12,544 12,292 12,229 12,300 1.37% 3.53%
26. Other 1,353 2,547 2,088 482 844 12.52% -46.88%
27. Total Sales 58,354 58,864 57,312 54,892 57,647 0.31% -0.87%
28. Estimated Overall Rate of Return 8.27% 8.36% 7.49% 7.91% 7.41% 2.78% -1.08%
29. Estimated Return on Members' Equity 10.83% 11.12% 9.56% 10.19% 9.08% 4.50% -2.61%
30. Members' Equity Ratio 56.38% 54.86% 53.48% 53.30% 53.24% 1.44% 2.77%
31. Debt Ratio 43.62% 45.14% 46.52% 46.70% 46.76% -1.72% -3.37%
32. Estimated Pretax Interest Coverage
Ratio (Times) 5.36 5.38 4.44 4.66 4.15 6.61% -0.37%
33. LAST RATE CASE Authorized Returns: Common Equity 10.20%, Overall 7.88%; Equity Ratio: 53.00%; Date of Order: 9-24-13
(Docket No. E-7, Sub 1026)
Notes: [1] North Carolina retail jurisdictional revenue equates to 69% of total company electric utility revenue.
[2] Net Plant Investment reflects net plant in service.
[3] Source of Data: NCUC ES-1 Reports.
[4] ROEs for the 12 months ended: 3-31-2015,12-31-2014, 9-30-2014, and 6-30-2014, are respectively: 10.75%, 10.73%, 10.99%, and 11.12%.
[5] The increase from June 2012 to June 2013 in "Other" annual sales volume (millions kWh) can be attributed to energy sales
by DEC to Duke Energy Progress, LLC, d/b/a Duke Energy Progress (DEP) pursuant to the Joint Dispatch Agreement between
DEC and DEP filed in Docket Nos. E-2, Sub 998 and E-7, Sub 986.
[6] According to the Company, no cost (i.e., neither direct nor indirect) associated with the cleanup of the Dan River coal ash spill
has been included in either capital and/or operating costs assigned to the Company's North Carolina retail jurisdiction for
ES-1 reporting purposes.
15
12 Months Ended Growth Rate
DUKE ENERGY CAROLINAS, LLC
SELECTED FINANCIAL AND OPERATIONAL DATA
North Carolina Retail Jurisdiction
(Amounts In Thousands)
Line June June June June June Four Current
No. Item 2015 2014 2013 2012 2011 Year Year
(a) (b) (c) (d) (e) (f) (g) (h)
1. Operating Revenue $3,595,238 $3,639,033 $3,458,288 $3,299,561 $3,476,509 0.84% -1.20%
2. Operating Expenses:
3. Fuel 1,038,914 985,145 1,029,677 939,440 1,053,985 -0.36% 5.46%
4. Purchased Power 289,454 327,270 273,832 217,451 211,208 8.20% -11.55%
5. Maintenance 409,145 360,567 266,288 341,319 243,999 13.79% 13.47%
6. Other Operating Expenses 632,796 612,873 720,727 690,167 647,567 -0.58% 3.25%
7. Total Operating Expenses 2,370,309 2,285,855 2,290,524 2,188,377 2,156,759 2.39% 3.69%
8. Depreciation & Amortization 427,424 375,944 331,781 358,670 329,142 6.75% 13.69%
9. Total Expenses & Depreciation 2,797,733 2,661,799 2,622,305 2,547,047 2,485,901 3.00% 5.11%
10. Total Operating Taxes 289,585 434,638 400,250 322,097 442,288 -10.05% -33.37%
11. Total Expenses, Depr. & Taxes 3,087,318 3,096,437 3,022,555 2,869,144 2,928,189 1.33% -0.29%
12. Operating Income $507,920 $542,596 $435,733 $430,417 $548,320 -1.90% -6.39%
13. Net Plant Investment $9,101,936 $6,583,595 $6,475,994 $6,139,848 $5,885,077 11.52% 38.25%
14. Oper. Exp. as a % of Total Revenue 65.93% 62.81% 66.23% 66.32% 62.04% 1.53% 4.97%
15. Net Plt. Investment per $ of Revenue $2.53 $1.81 $1.87 $1.86 $1.69 10.61% 39.78%
16. Number of Customers Served (000s included):
17. Residential 1,137,649 1,119,446 1,106,442 1,114,978 1,107,208 0.68% 1.63%
18. Commercial 195,288 192,549 190,941 194,208 192,551 0.35% 1.42%
19. Industrial 3,559 3,597 3,686 3,912 3,939 -2.50% -1.06%
20. Other 1,388 1,415 1,508 1,532 1,643 -4.13% -1.91%
21. Total Number of Customers 1,337,884 1,317,007 1,302,577 1,314,630 1,305,341 0.62% 1.59%
22. Annual Sales Volume: (Millions kWh)
23. Residential 15,884 15,865 15,318 14,690 16,470 -0.90% 0.12%
24. Commercial 12,187 12,114 11,911 11,895 12,369 -0.37% 0.60%
25. Industrial 7,857 8,069 8,267 8,392 8,415 -1.70% -2.63%
26. Other 5,501 4,562 4,292 1,939 1,164 47.44% 20.58%
27. Total Sales 41,429 40,610 39,788 36,916 38,418 1.90% 2.02%
28. Estimated Overall Rate of Return 7.18% 8.06% 7.11% 7.06% 9.87% -7.65% -10.92%
29. Estimated Return on Common Equity 9.82% 11.29% 9.42% 8.71% 13.09% -6.93% -13.02%
30. Common Equity Ratio 52.21% 53.40% 52.44% 55.67% 59.01% -3.01% -2.23%
31. Debt Ratio 47.79% 46.60% 47.16% 43.72% 40.34% 4.33% 2.55%
32. Estimated Pretax Interest Coverage
Ratio (Times) 4.94 5.76 4.91 4.29 6.88 -7.95% -14.24%
33. LAST RATE CASE Authorized Returns: Common Equity 10.20%, Overall 7.55%; Equity Ratio: 53.00%; Date of Order: 5-30-13
(Docket No. E-2, Sub 1023)
Notes: [1] North Carolina retail jurisdictional revenue equates to 69% of total company electric utility revenue.
[2] Net Plant Investment reflects net plant in service.
[3] Source of Data: NCUC ES-1 Reports.
[4] ROEs for the 12 months ended: 3-31-2015,12-31-2014, 9-30-2014, and 6-30-2014, are respectively: 10.41%, 10.13%, 10.57%, and 11.29%.
[5] On Line 13, the increase from June 2014 to June 2015 in net plant investment was primarily due to a change in reporting by DEP to
include its asset retirement obligations.
[6] The decrease from June 2012 to June 2013 in the number of customers was primarily due to a change in reporting by DEP.
Beginning with the December 2012 NCUC ES-1 Report, PEC now reports the number of active customers rather than the
total number of customers which includes both active and inactive customers.
[7] The increase from June 2012 to June 2013 in "Other" annual sales volume (millions kWh) can be attributed to energy
sales by DEP to Duke Energy Carolinas, LLC (DEC) pursuant to the Joint Dispatch Agreement between DEC and DEP filed
in Docket Nos. E-2, Sub 998 and E-7, Sub 986.
[8] Effective August 1, 2015, Duke Energy Progress, Inc. was converted to a limited liability corporation.
16
Growth Rate
Annual
12 Months Ended
DUKE ENERGY PROGRESS, LLC, d/b/a
DUKE ENERGY PROGRESS
SELECTED FINANCIAL AND OPERATIONAL DATA
North Carolina Retail Jurisdiction
(Amounts In Thousands)
Annual
Line June June June June June Four Current
No. Item 2015 2014 2013 2012 2011 Year Year
(a) (b) (c) (d) (e) (f) (g) (h)
1. Operating Revenue $374,931 $378,974 $361,939 $320,030 $335,657 2.80% -1.07%
2. Operating Expenses:
3. Fuel 95,004 70,655 77,594 65,591 62,914 10.85% 34.46%
4. Purchased Power 45,386 56,247 57,251 68,874 87,293 -15.08% -19.31%
5. Maintenance 0 0 0 0 0 N/A N/A
6. Other Operating Expenses 82,419 87,438 69,548 79,776 75,418 2.24% -5.74%
7. Total Operating Expenses 222,809 214,340 204,393 214,241 225,625 -0.31% 3.95%
8. Depreciation & Amortization 53,531 49,089 46,259 48,800 34,879 11.30% 9.05%
9. Total Expenses & Depreciation 276,340 263,429 250,652 263,041 260,504 1.49% 4.90%
10. Total Operating Taxes 41,088 40,484 38,043 31,839 36,348 3.11% 1.49%
11. Total Expenses, Depr. & Taxes 317,428 303,913 288,695 294,880 296,852 1.69% 4.45%
12. Operating Income $57,503 $75,061 $73,244 $25,150 $38,805 10.33% -23.39%
13. Net Plant Investment $1,140,296 $1,023,471 $945,169 $813,185 $808,263 8.98% 11.41%
14. Oper. Exp. as a % of Total Revenue 59.43% 56.56% 56.47% 66.94% 67.22% -3.03% 5.07%
15. Net Plt. Investment per $ of Revenue $3.04 $2.70 $2.61 $2.54 $2.41 5.98% 12.59%
16. Number of Customers Served (000s included):
17. Residential 101,598 101,233 101,088 101,054 101,150 0.11% 0.36%
18. Commercial 15,682 15,610 15,569 15,513 15,397 0.46% 0.46%
19. Industrial 52 51 50 50 53 -0.48% 1.96%
20. Other 2,236 2,236 2,240 2,239 2,247 -0.12% 0.00%
21. Total Number of Customers 119,568 119,130 118,947 118,856 118,847 0.15% 0.37%
22. Annual Sales Volume: (Millions kWh)
23. Residential 1,651 1,635 1,598 1,485 1,695 -0.66% 0.98%
24. Commercial 847 866 887 812 817 0.91% -2.19%
25. Industrial 1,806 1,794 1,645 1,629 1,623 2.71% 0.67%
26. Other 138 138 136 135 146 -1.40% 0.00%
27. Total Sales 4,442 4,433 4,266 4,061 4,281 0.93% 0.20%
28. Estimated Overall Rate of Return 6.30% 8.84% 9.45% 3.31% 6.26% 0.16% -28.73%
29. Estimated Return on Common Equity 7.69% 12.19% 12.86% 1.60% 6.90% 2.75% -36.92%
30. Common Equity Ratio 53.04% 53.93% 55.42% 54.79% 54.54% -0.69% -1.65%
31. Debt Ratio 46.75% 44.88% 43.06% 43.64% 43.81% 1.64% 4.17%
32. Estimated Pretax Interest Coverage
Ratio (Times) 3.96 4.90 5.19 1.99 3.61 2.34% -19.18%
33. LAST RATE CASE Authorized Returns: Common Equity - 10.20%, Overall - 7.80%; Equity Ratio: 51.00%; Date of Order: 12-21-12
(Docket No. E-22, Sub 479)
Notes: [1] North Carolina retail jurisdictional revenue equates to 5% of total company electric utility revenue.
[2] Net Plant Investment reflects net plant in service.
[3] Source of Data: NCUC ES-1 Reports.
[4] ROEs for the 12 months ended: 3-31-2015,12-31-2014, 9-30-2014, and 6-30-2014, are respectively: 8.66%, 7.97%, 9.13%, and 12.19%.
[5] The results for the 12 months ended June 30, 2013, include a one-time reduction in deferred tax expense of approximately
$12.5 million related to a change in state tax apportionment methodology. According to the Company, the return on common
equity for the 12 months ended June 30, 2013, excluding such non-recurring amount, would have been 11.25%.
[6] The results for the 12 months ended June 30, 2014, reflect income tax reductions related to (i) an adjustment to North Carolina
state accumulated deferred income taxes to recognize tax rate reductions effective January 1, 2014 and January 1, 2015, as enacted
in 2013 North Carolina Session Law 2013-316 (HB 998), and (ii) a change in the Company's determination of North Carolina state
income taxes which DNCP reported on amended returns filed in 2013 that have been reviewed by the North Carolina Department of
Revenue (NCDOR). The NCDOR notified DNCP in September 2015 that it was denying a portion of the refund claims reported on the
amended returns. DNCP is presently evaluating its options for appeal. According to the Company, the return on common equity
for the 12 months ended June 30, 2014, excluding such adjustments, would have been 10.32%.
[7] N/A denotes that the data is not available or not applicable or that information is, essentially, unmeaningful. 17
VIRGINIA ELECTRIC AND POWER COMPANY, d/b/a
Growth Rate
DOMINION NORTH CAROLINA POWER
SELECTED FINANCIAL AND OPERATIONAL DATA
North Carolina Retail Jurisdiction
(Amounts In Thousands)
12 Months Ended
18
Annual
Growth Rate
Line June June June June June Four Current
No. Item 2015 2014 2013 2012 2011 Year Year
(a) (b) (c) (d) (e) (f) (g) (h)
1. Operating Revenue:
2. Residential $440,446 $462,405 $404,678 $380,275 $456,142 -0.87% -4.75%
3. Commercial 253,463 264,460 225,159 218,442 267,017 -1.29% -4.16%
4. Industrial 23,615 23,277 18,066 18,492 26,015 -2.39% 1.45%
5. Public Authorities 824 907 307 447 657 5.83% -9.15%
6. Other 150,705 158,938 123,292 87,275 86,568 14.87% -5.18%
7. Total Operating Revenue 869,053 909,987 771,502 704,931 836,399 0.96% -4.50%
8. Cost of Gas 370,332 442,910 350,874 310,084 448,270 -4.66% -16.39%
9. Margin 498,721 467,077 420,628 394,847 388,129 6.47% 6.77%
10. O & M Expenses 203,915 190,695 177,083 165,700 159,113 6.40% 6.93%
11. Other Deductions 161,505 152,249 140,994 132,531 126,603 6.28% 6.08%
12. Operating Income $133,301 $124,133 $102,551 $96,616 $102,413 6.81% 7.39%
13. Net Plant Investment $2,965,918 $2,703,954 $2,335,690 $1,851,176 $1,706,090 14.83% 9.69%
14. Operating Exp. as a % of Margin 40.89% 40.83% 42.10% 41.97% 40.99% -0.06% 0.15%
15. Net Plt. Investment per $ of Margin $5.95 $5.79 $5.55 $4.69 $4.40 7.84% 2.76%
16. Gas Delivered in DTs (000s omitted):
17. Residential 39,819 40,766 37,553 29,392 38,426 0.89% -2.32%
18. Commercial 30,754 30,705 28,439 23,689 28,353 2.05% 0.16%
19. Industrial 3,362 3,103 2,679 2,676 3,376 -0.10% 8.35%
20. Public Authorities 74 73 65 48 66 2.90% 1.37%
21. Other 315,473 279,172 253,249 188,131 143,209 21.83% 13.00%
22. Total DTs 389,482 353,819 321,985 243,936 213,430 16.23% 10.08%
23. Number of Customers (000s included):
24. Residential 633,163 624,116 615,223 605,438 601,521 1.29% 1.45%
25. Commercial 67,433 66,444 65,442 64,772 64,061 1.29% 1.49%
26. Industrial 1,084 1,079 1,066 1,080 1,092 -0.18% 0.46%
27. Public Authorities 1,800 1,801 1,807 1,576 1,576 3.38% -0.06%
28. Other 605 603 600 592 566 1.68% 0.33%
29. Total Number of Customers 704,085 694,043 684,138 673,458 668,816 1.29% 1.45%
30. Estimated Overall Rate of Return 6.12% 6.49% 7.16% 7.62% 8.22% -7.11% -5.70%
31. Estimated Return on Common Equity 8.85% 9.75% 11.15% 10.85% 10.80% -4.86% -9.23%
32. Common Equity Ratio 43.83% 44.17% 45.44% 50.00% 51.72% -4.05% -0.77%
33. Debt Ratio 56.17% 55.83% 54.56% 50.00% 48.28% 3.86% 0.61%
34. Estimated Pretax Interest Coverage
Ratio (Times) 3.87 4.26 5.02 5.07 4.50 -3.70% -9.15%
35. LAST RATE CASE Authorized Returns: Common Equity 10.00%, Overall 7.51%; Equity Ratio: 50.66%; Date of Order: 12-17-13
(Docket No. G-9, Sub 631)
Notes:
[1] North Carolina retail jurisdictional revenue equates to approximately 69% of total company gas utility revenue.
[2] Net Plant Investment reflects net plant in service.
[3] Source of Data: Shareholders' reports and the NCUC GS-1 Reports.
[4] ROEs for the 12 months ended: 3-31-2015,12-31-2014, 9-30-2014, and 6-30-2014, are respectively: 8.96%, 8.78%, 8.92%, and 9.75%.
12 Months Ended
(Amounts In Thousands)
PIEDMONT NATURAL GAS COMPANY, INC.
SELECTED FINANCIAL AND OPERATIONAL DATA
North Carolina Jurisdiction
Annual
Growth Rate
Line June June June June June Four Current
No. Item 2015 2014 2013 2012 2011 Year Year
(a) (b) (c) (d) (e) (f) (g) (h)
1. Operating Revenue:
2. Residential $326,486 $364,049 $331,759 $253,259 $330,649 -0.32% -10.32%
3. Commercial 124,238 138,606 120,702 100,146 128,154 -0.77% -10.37%
4. Industrial 19,396 16,906 16,202 14,718 19,542 -0.19% 14.73%
5. Public Authorities 0 0 0 0 0 N/A N/A
6. Resale 0 0 0 1 4 N/A N/A
7. Other 31,435 38,238 30,385 27,346 27,168 3.71% -17.79%
8. Total Operating Revenue 501,555 557,799 499,048 395,470 505,517 -0.20% -10.08%
9. Cost of Gas 255,787 317,738 264,960 166,591 280,429 -2.27% -19.50%
10. Margin 245,768 240,061 234,088 228,879 225,088 2.22% 2.38%
11. O & M Expenses 89,486 87,520 86,034 85,669 84,005 1.59% 2.25%
12. Other Deductions 88,203 84,825 81,411 78,383 75,283 4.04% 3.98%
13. Operating Income $68,079 $67,716 $66,643 $64,827 $65,800 0.85% 0.54%
14. Net Plant Investment $904,119 $865,685 $851,284 $826,722 $781,478 3.71% 4.44%
15. Operating Exp. as a % of Margin 36.41% 36.46% 36.75% 37.43% 37.32% -0.62% -0.14%
16. Net Plt. Investment per $ of Margin $3.68 $3.61 $3.64 $3.61 $3.47 1.48% 1.94%
17. Gas Delivered in DTs (000s omitted):
18. Residential 30,945 30,668 27,872 21,657 28,256 2.30% 0.90%
19. Commercial 15,718 15,554 14,086 11,770 14,093 2.77% 1.05%
20. Industrial 3,352 2,687 3,037 2,515 2,872 3.94% 24.75%
21. Public Authorities 0 0 0 0 0 N/A N/A
22. Resale 0 0 0 0 0 N/A N/A
23. Other 41,656 38,588 35,832 31,362 29,569 8.95% 7.95%
24. Total DTs 91,671 87,497 80,827 67,304 74,790 5.22% 4.77%
25. Number of Customers (000s included):
26. Residential 475,646 462,837 451,801 442,546 434,280 2.30% 2.77%
27. Commercial 42,742 41,979 41,406 41,043 40,081 1.62% 1.82%
28. Industrial 202 161 176 177 168 4.72% 25.47%
29. Public Authorities 0 0 0 0 0 N/A N/A
30. Resale 0 0 0 0 1 N/A N/A
31. Other 454 465 473 470 459 -0.27% -2.37%
32. Total Number of Customers 519,044 505,442 493,856 484,236 474,989 2.24% 2.69%
33. Estimated Overall Rate of Return 8.48% 9.07% 8.97% 8.90% 9.30% -2.28% -6.50%
34. Estimated Return on Common Equity 10.32% 11.31% 11.32% 11.31% 11.67% -3.03% -8.75%
35. Common Equity Ratio 59.29% 58.66% 57.19% 56.02% 55.25% 1.78% 1.07%
36. Debt Ratio 40.71% 41.34% 42.81% 43.98% 44.75% -2.34% -1.52%
37. Estimated Pretax Interest Coverage
Ratio (Times) 5.20 5.49 5.28 5.04 4.63 2.95% -5.28%
38. LAST RATE CASE Authorized Returns: Common Equity 10.60%, Overall 8.54%; Equity Ratio: 54.00%; Date of Order: 10-24-08
(Docket No. G-5, Sub 495)
Notes: [1] North Carolina retail jurisdictional revenue equates to 100% of total company gas utility service revenue.
[2] Net Plant Investment reflects net plant in service.
[3] Source of Data: Shareholders' Reports and the NCUC GS-1 Reports.
[4] ROEs for the 12 months ended: 3-31-2015,12-31-2014, 9-30-2014, and 6-30-2014, are respectively: 10.98%, 10.89%, 11.14%, and 11.31%.
[5] N/A denotes that the data is not available or not applicable or that information is, essentially, unmeaningful.
19
12 Months Ended
PUBLIC SERVICE COMPANY OF NORTH CAROLINA, INC.
SELECTED FINANCIAL AND OPERATIONAL DATA
North Carolina Jurisdiction
(Amounts In Thousands)
d/b/a PSNC Energy
Part IV
Telecommunications Companies
Annual Report Filings
Telecommunications Companies 2014 Annual Report Filings1
A. The following companies provided the Commission with links to their 2014 Annual
Report filings, as submitted to the SEC:
● BellSouth Telecommunications, LLC, d/b/a AT&T North Carolina –
http://www.sec.gov/Archives/edgar/data/732717/000073271715000016/0000732717-15-
000016-index.htm
● Carolina Telephone and Telegraph Company LLC, d/b/a CenturyLink; Central
Telephone Company, d/b/a CenturyLink; and Mebtel, Inc., d/b/a CenturyLink –
http://www.sec.gov/Archives/edgar/data/18926/000001892615000008/ctl-
2014123110k.htm
● Frontier Communications of the Carolinas, Inc. –
http://investor.frontier.com/secfiling.cfm?filingID=20520-15-11&CIK=20520
● Verizon South Inc.2 –
http://www.verizon.com/investor/quicklink.htm
● Windstream Concord Telephone, Inc.; Windstream Lexcom Communications, Inc.;and
Windstream North Carolina, LLC –
http://abea-43pvyw.client.shareholder.com/investors/sec.cfm
B. The following companies provided the Commission with copies of their 2014
audited financial statements:
● North State Telephone Company, d/b/a North State Communications
● Citizens Telephone Company, d/b/a Comporium3
1 The deadline for a price plan regulated company to either provide its annual report to the Commission or to otherwise
satisfy its annual reporting obligations under Commission Rule R1-32, Subsection (e1) is as soon as possible after the
close of the calendar year, but in no event later than the 30th day of April each year for the preceding calendar year.
2 Verizon South, Inc. Knotts Island Exchange.
3 Such report has been provided as confidential and proprietary information.
21
Part V - Appendix A
Quarterly Review Electronic Distribution List
Commission Staff
Daniel Conrad
Kimberly Duffley
Roy Ericson
Corrie Foster
Bill Gilmore
Len Green
Freda Hilburn
Lemuel Hinton
Don Hoover
Kim Jones
Bliss Kite
Gail Mount
Bridget Paschal
George Sessoms
Sam Watson
Public Staff
Christopher Ayers
Jeff Davis
David Furr
John Garrison
Carl Goolsby
Robert Hinton
Jim Hoard
James McLawhorn
Antoinette Wike
Attorney General’s Office
Margaret Force
Others
Alexander Bailey
Virginia Electric and Power
Company, d/b/a Dominion North
Carolina Power
David Baker
North Carolina Department of Revenue
Laura Bateman, Manager
Carolinas Rates & Regulatory Strategy
Duke Energy
Robert H. Bennink, Jr.
Bennink Law Office
Brett Breitschwerdt
McGuire Woods LLP
David Carpenter
Managing Director Regulatory Affairs
Piedmont Natural Gas Company, Inc.
Matthew L. Dosch
Senior Vice President of
External Affairs
Comporium Communications
Rick Feathers
Associate General Counsel
N.C. Electric Corporation
Mary Lynne Grigg
McGuire Woods LLP
Greg Locke
ElectriCities of North Carolina
William McAulay, Vice President
Economic Development,
Governmental and Regulatory Affairs
Public Service Company of NC, Inc.
Ralph McDonald
Bailey & Dixon, LLP
Sharon Miller
Carolina Utility Customers
Association, Inc.
Kevin O’Donnell
Nova Energy Consultants
Adam Olls
Bailey & Dixon, LLP
Stan Pace, Director
State Government Relations
Frontier Communications of
the Carolinas Inc.
Robert F. Page
Crisp, Page & Currin, L.L.P.
Candace A. Paton, Lead Analyst
Rates & Regulatory Affairs
Public Service Company of NC, Inc.
Pia K. Powers
Manager Regulatory Affairs
Piedmont Natural Gas
Company, Inc.
Jo Anne Sanford
Sanford Law Office, PLLC
Carol Shrum, Vice President Rates
Duke Energy Corporation
Heather Shirley Smith
Deputy General Counsel
Duke Energy Carolinas, LLC
Robert Smith, Director-External Affairs
BellSouth Telecommunications, Inc.,
d/b/a AT&T North Carolina
Lawrence Somers
Deputy General Counsel
Duke Energy Corporation
State Library of North Carolina
Laura A. Sykora
Regulatory Affairs Manager
CenturyLink
David Tsai
Regulatory Affairs Manager
Duke Energy
Royster M. Tucker, Jr.
North State Telephone Company,
d/b/a North State Communications
Susan Warner
Bailey & Dixon, LLP
Bob Wells, Executive Director
North Carolina Telephone Alliance
Bettye J. Willis
Regional Vice President
State Government Affairs
Windstream Communications, Inc.