Document


UNITED STATES SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM 10-Q
(Mark One)
ý
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended June 30, 2016
OR
¨
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from              to
________________________
Commission file number
Registrant, State of Incorporation or Organization,
Address of Principal Executive Offices, and Telephone Number
IRS Employer Identification No.
 
 
1-32853
DUKE ENERGY CORPORATION
(a Delaware corporation)
550 South Tryon Street
Charlotte, North Carolina 28202-1803
704-382-3853
20-2777218
Commission file number
Registrant, State of Incorporation or Organization, Address of Principal Executive Offices, Telephone Number and IRS Employer Identification Number
 
Commission file number
Registrant, State of Incorporation or Organization, Address of Principal Executive Offices, Telephone Number and IRS Employer Identification Number
1-4928
DUKE ENERGY CAROLINAS, LLC
(a North Carolina limited liability company)
526 South Church Street
Charlotte, North Carolina 28202-1803
704-382-3853
56-0205520
 
1-3274
DUKE ENERGY FLORIDA, LLC
(a Florida limited liability company)
299 First Avenue North
St. Petersburg, Florida 33701
704-382-3853
59-0247770
1-15929
PROGRESS ENERGY, INC.
(a North Carolina corporation)
410 South Wilmington Street
Raleigh, North Carolina 27601-1748
704-382-3853
56-2155481
 
1-1232
DUKE ENERGY OHIO, INC.
(an Ohio corporation)
139 East Fourth Street
Cincinnati, Ohio 45202
704-382-3853
31-0240030
1-3382
DUKE ENERGY PROGRESS, LLC
(a North Carolina limited liability company)
410 South Wilmington Street
Raleigh, North Carolina 27601-1748
704-382-3853
56-0165465
 
1-3543
DUKE ENERGY INDIANA, LLC
(an Indiana limited liability company)
1000 East Main Street
Plainfield, Indiana 46168
704-382-3853
35-0594457
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.
Duke Energy Corporation (Duke Energy)
Yes x
No ¨
 
Duke Energy Florida, LLC (Duke Energy Florida)
Yes x
No ¨
Duke Energy Carolinas, LLC (Duke Energy Carolinas)
Yes x
No ¨
 
Duke Energy Ohio, Inc. (Duke Energy Ohio)
Yes x
No ¨
Progress Energy, Inc. (Progress Energy)
Yes x
No ¨
 
Duke Energy Indiana, LLC (Duke Energy Indiana)
Yes x
No ¨
Duke Energy Progress, LLC (Duke Energy Progress)
Yes x
No ¨
 
 
 
 




Indicate by check mark whether the registrant has submitted electronically and posted on its corporate website, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).
Duke Energy
Yes x
No ¨
 
Duke Energy Florida
Yes x
No ¨
Duke Energy Carolinas
Yes x
No ¨
 
Duke Energy Ohio
Yes x
No ¨
Progress Energy
Yes x
No ¨
 
Duke Energy Indiana
Yes x
No ¨
Duke Energy Progress
Yes x
No ¨
 
 
 
 
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.
Duke Energy
Large accelerated filer x
Accelerated filer ¨
Non-accelerated filer ¨
Smaller reporting company ¨
Duke Energy Carolinas
Large accelerated filer ¨
Accelerated filer ¨
Non-accelerated filer x
Smaller reporting company ¨
Progress Energy
Large accelerated filer ¨
Accelerated filer ¨
Non-accelerated filer x
Smaller reporting company ¨
Duke Energy Progress
Large accelerated filer ¨
Accelerated filer ¨
Non-accelerated filer x
Smaller reporting company ¨
Duke Energy Florida
Large accelerated filer ¨
Accelerated filer ¨
Non-accelerated filer x
Smaller reporting company ¨
Duke Energy Ohio
Large accelerated filer ¨
Accelerated filer ¨
Non-accelerated filer x
Smaller reporting company ¨
Duke Energy Indiana
Large accelerated filer ¨
Accelerated filer ¨
Non-accelerated filer x
Smaller reporting company ¨
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).
Duke Energy
Yes ¨
No x
 
Duke Energy Florida
Yes ¨
No x
Duke Energy Carolinas
Yes ¨
No x
 
Duke Energy Ohio
Yes ¨
No x
Progress Energy
Yes ¨
No x
 
Duke Energy Indiana
Yes ¨
No x
Duke Energy Progress
Yes ¨
No x
 
 
 
 
Number of shares of Common stock outstanding at June 30, 2016:
Registrant
Description
Shares
Duke Energy
Common stock, $0.001 par value
688,933,508
Duke Energy Carolinas
All of the registrant's limited liability company member interests are directly owned by Duke Energy.
Progress Energy
All of the registrant's common stock is directly owned by Duke Energy.
Duke Energy Progress
All of the registrant's limited liability company member interests are indirectly owned by Duke Energy.
Duke Energy Florida
All of the registrant's limited liability company member interests are indirectly owned by Duke Energy.
Duke Energy Ohio
All of the registrant's common stock is indirectly owned by Duke Energy.
Duke Energy Indiana
All of the registrant's limited liability company member interests are indirectly owned by Duke Energy.
This combined Form 10-Q is filed separately by seven registrants: Duke Energy, Duke Energy Carolinas, Progress Energy, Duke Energy Progress, Duke Energy Florida, Duke Energy Ohio and Duke Energy Indiana (collectively the Duke Energy Registrants). Information contained herein relating to any individual registrant is filed by such registrant solely on its own behalf. Each registrant makes no representation as to information relating exclusively to the other registrants.
Duke Energy Carolinas, Progress Energy, Duke Energy Progress, Duke Energy Florida, Duke Energy Ohio and Duke Energy Indiana meet the conditions set forth in General Instructions H(1)(a) and (b) of Form 10-Q and are therefore filing this form with the reduced disclosure format specified in General Instructions H(2) of Form 10-Q.




TABLE OF CONTENTS
 
 
 
 
 
PART I. FINANCIAL INFORMATION
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Note 1 – Organization and Basis of Presentation
 
Note 2 – Acquisitions and Dispositions
 
Note 3 – Business Segments
 
Note 4 – Regulatory Matters
 
Note 5 – Commitments and Contingencies
 
Note 6 – Debt and Credit Facilities
 
Note 7 – Goodwill and Intangible Assets
 
Note 8 – Related Party Transactions
 
Note 9 – Derivatives and Hedging
 
Note 10 – Investments in Debt and Equity Securities
 
Note 11 – Fair Value Measurements
 
Note 12 – Variable Interest Entities
 
Note 13 – Common Stock
 
Note 14 – Stock-Based Compensation
 
Note 15 – Employee Benefit Plans
 
Note 16 – Income Taxes
 
Note 17 – Subsequent Events
 
 
 
 
 
 
 
 
 
 
 
 
PART II. OTHER INFORMATION
 
 
 
 
 
 
 
 
 
 
 
 
 





CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION
This document includes forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. Forward-looking statements are based on management’s beliefs and assumptions and can often be identified by terms and phrases that include “anticipate,” “believe,” “intend,” “estimate,” “expect,” “continue,” “should,” “could,” “may,” “plan,” “project,” “predict,” “will,” “potential,” “forecast,” “target,” “guidance,” “outlook” or other similar terminology. Various factors may cause actual results to be materially different than the suggested outcomes within forward-looking statements; accordingly, there is no assurance that such results will be realized. These factors include, but are not limited to:
State, federal and foreign legislative and regulatory initiatives, including costs of compliance with existing and future environmental requirements or climate change, as well as rulings that affect cost and investment recovery or have an impact on rate structures or market prices;
The extent and timing of costs and liabilities to comply with federal and state laws, regulations, and legal requirements related to coal ash remediation, including amounts for required closure of certain ash impoundments, are uncertain and difficult to estimate;
The ability to recover eligible costs, including amounts associated with coal ash impoundment retirement obligations and costs related to significant weather events, and to earn an adequate return on investment through the regulatory process;
The costs of decommissioning Crystal River Unit 3 and other nuclear facilities could prove to be more extensive than amounts estimated and all costs may not be fully recoverable through the regulatory process;
Credit ratings of the Duke Energy Registrants may be different from what is expected;
Costs and effects of legal and administrative proceedings, settlements, investigations and claims;
Industrial, commercial and residential growth or decline in service territories or customer bases resulting from variations in customer usage patterns, including energy efficiency efforts and use of alternative energy sources, including self-generation and distributed generation technologies;
Federal and state regulations, laws and other efforts designed to promote and expand the use of energy efficiency measures and distributed generation technologies, such as rooftop solar and battery storage, in Duke Energy service territories could result in customers leaving the electric distribution system, excess generation resources as well as stranded costs;
Advancements in technology;
Additional competition in electric markets and continued industry consolidation;
Political, economic and regulatory uncertainty in Brazil and other countries in which Duke Energy conducts business;
The influence of weather and other natural phenomena on operations, including the economic, operational and other effects of severe storms, hurricanes, droughts, earthquakes and tornadoes;
The ability to successfully operate electric generating facilities and deliver electricity to customers including direct or indirect effects to the company resulting from an incident that affects the U.S. electric grid or generating resources;
The impact on facilities and business from a terrorist attack, cybersecurity threats, data security breaches, and other catastrophic events such as fires, explosions, pandemic health events or other similar occurrences;
The inherent risks associated with the operation and potential construction of nuclear facilities, including environmental, health, safety, regulatory and financial risks;
The timing and extent of changes in commodity prices, interest rates and foreign currency exchange rates and the ability to recover such costs through the regulatory process, where appropriate, and their impact on liquidity positions and the value of underlying assets;
The results of financing efforts, including the ability to obtain financing on favorable terms, which can be affected by various factors, including credit ratings, interest rate fluctuations, and general economic conditions;
Declines in the market prices of equity and fixed income securities and resultant cash funding requirements for defined benefit pension plans, other post-retirement benefit plans and nuclear decommissioning trust funds;
Construction and development risks associated with the completion of Duke Energy Registrants’ capital investment projects, including risks related to financing, obtaining and complying with terms of permits, meeting construction budgets and schedules, and satisfying operating and environmental performance standards, as well as the ability to recover costs from customers in a timely manner or at all;
Changes in rules for regional transmission organizations, including changes in rate designs and new and evolving capacity markets, and risks related to obligations created by the default of other participants;
The ability to control operation and maintenance costs;
The level of creditworthiness of counterparties to transactions;
Employee workforce factors, including the potential inability to attract and retain key personnel;
The ability of subsidiaries to pay dividends or distributions to Duke Energy Corporation holding company (the Parent);
The performance of projects undertaken by our nonregulated businesses and the success of efforts to invest in and develop new opportunities;
The effect of accounting pronouncements issued periodically by accounting standard-setting bodies;
The impact of potential goodwill impairments;
The ability to successfully complete future merger, acquisition or divestiture plans;




The expected timing and likelihood of completion of the proposed acquisition of Piedmont Natural Gas Company, Inc. (Piedmont), including the timing, receipt and terms and conditions of any required governmental and regulatory approvals of the proposed acquisition that could reduce anticipated benefits or cause the parties to abandon the acquisition, and under certain specified circumstances pay a termination fee of $250 million, as well as the ability to successfully integrate the businesses and realize anticipated benefits and the risk that the credit ratings of the combined company or its subsidiaries may be different from what the companies expect; and
The likelihood, terms and timing of the potential sale of International Energy, excluding the equity investment in National Methanol Company (NMC), could change the presentation of certain assets, liabilities and results of operations as assets held for sale, liabilities associated with assets held for sale, and discontinued operations, respectively.
Additional risks and uncertainties are identified and discussed in the Duke Energy Registrants' reports filed with the SEC and available at the SEC's website at www.sec.gov. In light of these risks, uncertainties and assumptions, the events described in the forward-looking statements might not occur or might occur to a different extent or at a different time than described. Forward-looking statements speak only as of the date they are made and the Duke Energy Registrants expressly disclaim an obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise.



PART I. FINANCIAL INFORMATION


ITEM 1. FINANCIAL STATEMENTS

DUKE ENERGY CORPORATION
Condensed Consolidated Statements of Operations
(Unaudited)
 
Three Months Ended
 
Six Months Ended
 
June 30,
 
June 30,
(in millions, except per-share amounts)
2016

 
2015

 
2016

 
2015

Operating Revenues
 
 
 
 
 
 
 
Regulated electric
$
4,965

 
$
5,090

 
$
10,018

 
$
10,547

Nonregulated electric and other
422

 
403

 
822

 
780

Regulated natural gas
97

 
96

 
266

 
327

Total operating revenues
5,484

 
5,589

 
11,106

 
11,654

Operating Expenses
 
 
 
 
 
 
 
Fuel used in electric generation and purchased power – regulated
1,509

 
1,721

 
3,086

 
3,662

Fuel used in electric generation and purchased power – nonregulated
82

 
118

 
140

 
222

Cost of natural gas
21

 
26

 
81

 
137

Operation, maintenance and other
1,431

 
1,422

 
2,920

 
2,848

Depreciation and amortization
813

 
790

 
1,627

 
1,567

Property and other taxes
293

 
279

 
590

 
543

Impairment charges
195

 

 
198

 

Total operating expenses
4,344

 
4,356

 
8,642

 
8,979

Gains on Sales of Other Assets and Other, net
5

 
13

 
14

 
27

Operating Income
1,145

 
1,246

 
2,478

 
2,702

Other Income and Expenses
 
 
 
 
 
 
 
Equity in earnings of unconsolidated affiliates
15

 
23

 
23

 
36

Other income and expenses, net
92

 
72

 
171

 
146

Total other income and expenses
107

 
95

 
194

 
182

Interest Expense
500

 
403

 
1,011

 
806

Income From Continuing Operations Before Income Taxes
752

 
938

 
1,661

 
2,078

Income Tax Expense from Continuing Operations
239

 
334

 
452

 
698

Income From Continuing Operations
513

 
604

 
1,209

 
1,380

(Loss) Income From Discontinued Operations, net of tax
(1
)
 
(57
)
 
2

 
34

Net Income
512

 
547

 
1,211

 
1,414

Less: Net Income Attributable to Noncontrolling Interests
3

 
4

 
8

 
7

Net Income Attributable to Duke Energy Corporation
$
509

 
$
543

 
$
1,203

 
$
1,407

 
 
 
 
 
 
 
 
Earnings Per Share – Basic and Diluted
 
 
 
 
 
 
 
Income from continuing operations attributable to Duke Energy Corporation common stockholders
 
 
 
 
 
 
 
Basic
$
0.74

 
$
0.87

 
$
1.74

 
$
1.96

Diluted
$
0.74

 
$
0.87

 
$
1.74

 
$
1.96

(Loss) Income from discontinued operations attributable to Duke Energy Corporation common stockholders
 
 
 
 
 
 
 
Basic
$

 
$
(0.09
)
 
$

 
$
0.05

Diluted
$

 
$
(0.09
)
 
$

 
$
0.05

Net income attributable to Duke Energy Corporation common stockholders
 
 
 
 
 
 
 
Basic
$
0.74

 
$
0.78

 
$
1.74

 
$
2.01

Diluted
$
0.74

 
$
0.78

 
$
1.74

 
$
2.01

Weighted average shares outstanding
 
 
 
 
 
 
 
Basic
689

 
692

 
689

 
700

Diluted
690

 
692

 
689

 
700


See Notes to Condensed Consolidated Financial Statements
6


PART I

DUKE ENERGY CORPORATION
Condensed Consolidated Statements of Comprehensive Income
(Unaudited)
 
Three Months Ended
 
Six Months Ended
 
June 30,
 
June 30,
(in millions)
2016

 
2015

 
2016

 
2015

Net Income
$
512

 
$
547

 
$
1,211

 
$
1,414

Other Comprehensive Income (Loss), net of tax
 
 
 
 
 
 
 
Foreign currency translation adjustments
58

 
9

 
107

 
(116
)
Pension and OPEB adjustments
2

 
7

 
2

 
2

Net unrealized (losses) gains on cash flow hedges
(11
)
 
9

 
(25
)
 
2

Reclassification into earnings from cash flow hedges

 
1

 
2

 
5

Unrealized gains (losses) on available-for-sale securities
3

 
(3
)
 
7

 
(3
)
Other Comprehensive Income (Loss), net of tax
52

 
23

 
93

 
(110
)
Comprehensive Income
564

 
570

 
1,304

 
1,304

Less: Comprehensive Income Attributable to Noncontrolling Interests
6

 
3

 
12

 
2

Comprehensive Income Attributable to Duke Energy Corporation
$
558

 
$
567

 
$
1,292

 
$
1,302



See Notes to Condensed Consolidated Financial Statements
7


PART I

DUKE ENERGY CORPORATION
Condensed Consolidated Balance Sheets
(Unaudited)
(in millions)
June 30, 2016
 
December 31, 2015
ASSETS
 
 
 
Current Assets
 
 
 
Cash and cash equivalents
$
676

 
$
857

Receivables (net of allowance for doubtful accounts of $23 at 2016 and $18 at 2015)
575

 
703

Receivables of VIEs (net of allowance for doubtful accounts of $56 at 2016 and $53 at 2015)
1,943

 
1,748

Inventory
3,627

 
3,810

Regulatory assets (includes $34 related to VIEs at 2016)
825

 
877

Other
451

 
327

Total current assets
8,097

 
8,322

Investments and Other Assets
 
 
 
Investments in equity method unconsolidated affiliates
613

 
499

Nuclear decommissioning trust funds
5,966

 
5,825

Goodwill
16,357

 
16,343

Other
2,972

 
3,042

Total investments and other assets
25,908

 
25,709

Property, Plant and Equipment
 
 
 
Cost
115,143

 
112,826

Accumulated depreciation and amortization
(38,412
)
 
(37,665
)
Generation facilities to be retired, net
598

 
548

Net property, plant and equipment
77,329

 
75,709

Regulatory Assets and Deferred Debits
 
 
 
Regulatory assets (includes $1,194 related to VIEs at 2016)
11,290

 
11,373

Other
30

 
43

Total regulatory assets and deferred debits
11,320

 
11,416

Total Assets
$
122,654

 
$
121,156

LIABILITIES AND EQUITY
 
 
 
Current Liabilities
 
 
 
Accounts payable
$
2,221

 
$
2,400

Notes payable and commercial paper
2,312

 
3,633

Taxes accrued
467

 
348

Interest accrued
448

 
430

Current maturities of long-term debt (includes $197 at 2016 and $125 at 2015 related to VIEs)
2,342

 
2,074

Regulatory liabilities
332

 
400

Other
1,784

 
2,115

Total current liabilities
9,906

 
11,400

Long-Term Debt (includes $3,383 at 2016 and $2,197 at 2015 related to VIEs)
39,931

 
37,495

Deferred Credits and Other Liabilities
 
 
 
Deferred income taxes
13,038

 
12,705

Investment tax credits
492

 
472

Accrued pension and other post-retirement benefit costs
1,044

 
1,088

Asset retirement obligations
10,231

 
10,264

Regulatory liabilities
6,334

 
6,255

Other
1,730

 
1,706

Total deferred credits and other liabilities
32,869

 
32,490

Commitments and Contingencies


 


Equity
 
 
 
Common stock, $0.001 par value, 2 billion shares authorized; 689 million and 688 million shares outstanding at 2016 and 2015, respectively
1

 
1

Additional paid-in capital
37,984

 
37,968

Retained earnings
2,627

 
2,564

Accumulated other comprehensive loss
(717
)
 
(806
)
Total Duke Energy Corporation stockholders' equity
39,895

 
39,727

Noncontrolling interests
53

 
44

Total equity
39,948

 
39,771

Total Liabilities and Equity
$
122,654

 
$
121,156


See Notes to Condensed Consolidated Financial Statements
8


PART I

DUKE ENERGY CORPORATION
Condensed Consolidated Statements of Cash Flows
(Unaudited)
 
Six Months Ended
 
June 30,
(in millions)
2016

 
2015

CASH FLOWS FROM OPERATING ACTIVITIES
 
 
 
Net income
$
1,211

 
$
1,414

Adjustments to reconcile net income to net cash provided by operating activities:
 
 
 
Depreciation, amortization and accretion (including amortization of nuclear fuel)
1,868

 
1,784

Equity component of AFUDC
(87
)
 
(82
)
Gains on sales of other assets
(18
)
 
(29
)
Impairment charges
198

 
37

Deferred income taxes
285

 
699

Equity in earnings of unconsolidated affiliates
(23
)
 
(36
)
Accrued pension and other post-retirement benefit costs
8

 
36

Contributions to qualified pension plans

 
(132
)
Payments for asset retirement obligations
(263
)
 
(125
)
(Increase) decrease in
 
 
 
Net realized and unrealized mark-to-market and hedging transactions
199

 
(29
)
Receivables
(57
)
 
105

Inventory
178

 
2

Other current assets
(51
)
 
(161
)
Increase (decrease) in
 
 
 
Accounts payable
(153
)
 
(288
)
Taxes accrued
216

 
(29
)
Other current liabilities
(281
)
 
(145
)
Other assets
(9
)
 
(63
)
Other liabilities
(15
)
 
(79
)
Net cash provided by operating activities
3,206

 
2,879

CASH FLOWS FROM INVESTING ACTIVITIES
 
 
 
Capital expenditures
(3,393
)
 
(3,062
)
Investment expenditures
(136
)
 
(98
)
Acquisitions

 
(29
)
Purchases of available-for-sale securities
(3,033
)
 
(2,187
)
Proceeds from sales and maturities of available-for-sale securities
3,059

 
2,200

Net proceeds from the sale of the Disposal Group

 
2,792

Net proceeds from the sales of equity investments and other assets
2

 
40

Change in restricted cash
(21
)
 
(3
)
Other
(86
)
 
53

Net cash used in investing activities
(3,608
)
 
(294
)
CASH FLOWS FROM FINANCING ACTIVITIES
 
 
 
Proceeds from the:
 
 
 
Issuance of long-term debt
3,514

 
574

Issuance of common stock related to employee benefit plans
7

 
16

Payments for the redemption of long-term debt
(795
)
 
(1,246
)
Proceeds from the issuance of short-term debt with original maturities greater than 90 days
500

 
287

Payments for the redemption of short-term debt with original maturities greater than 90 days
(492
)
 
(664
)
Notes payable and commercial paper
(1,349
)
 
12

Distributions to noncontrolling interests
(3
)
 
(7
)
Dividends paid
(1,140
)
 
(1,115
)
Repurchase of common shares

 
(1,500
)
Other
(21
)
 
(18
)
Net cash provided by (used in) financing activities
221

 
(3,661
)
Net decrease in cash and cash equivalents
(181
)
 
(1,076
)
Cash and cash equivalents at beginning of period
857

 
2,036

Cash and cash equivalents at end of period
$
676

 
$
960

Supplemental Disclosures:
 
 
 
Significant non-cash transactions:
 
 
 
Accrued capital expenditures
$
670

 
$
547


See Notes to Condensed Consolidated Financial Statements
9


PART I

DUKE ENERGY CORPORATION
Condensed Consolidated Statements of Changes in Equity
(Unaudited)
 
 
 
 
 
 
 
 
 
Accumulated Other Comprehensive Loss
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Net Unrealized

 
 
 
Total

 
 
 
 
 
 
 
 
 
 
 
 
 
Foreign

 
Net

 
Gains (Losses)

 
 
 
Duke Energy

 
 
 
 
 
Common

 
 
 
Additional

 
 
 
Currency

 
Losses on

 
on Available-

 
Pension and

 
Corporation

 
 
 
 
 
Stock

 
Common

 
Paid-in

 
Retained

 
Translation

 
Cash Flow

 
for-Sale-

 
OPEB

 
Stockholders'

 
Noncontrolling

 
Total

(in millions)
Shares

 
Stock

 
Capital

 
Earnings

 
Adjustments

 
Hedges

 
Securities

 
Adjustments

 
Equity

 
Interests

 
Equity

Balance at December 31, 2014
707

 
$
1

 
$
39,405

 
$
2,012

 
$
(439
)
 
$
(59
)
 
$
3

 
$
(48
)
 
$
40,875

 
$
24

 
$
40,899

Net income

 

 

 
1,407

 

 

 

 

 
1,407

 
7

 
1,414

Other comprehensive (loss) income

 

 

 

 
(111
)
 
7

 
(3
)
 
2

 
(105
)
 
(5
)
 
(110
)
Common stock issuances, including dividend reinvestment and employee benefits
1

 

 
28

 

 

 

 

 

 
28

 

 
28

Stock repurchase
(20
)
 

 
(1,500
)
 

 

 

 

 

 
(1,500
)
 

 
(1,500
)
Common stock dividends

 

 

 
(1,115
)
 

 

 

 

 
(1,115
)
 

 
(1,115
)
Distributions to noncontrolling interest in subsidiaries

 

 

 

 

 

 

 

 

 
(7
)
 
(7
)
Other(a)

 

 

 
(10
)
 

 

 

 

 
(10
)
 
18

 
8

Balance at June 30, 2015
688

 
$
1


$
37,933


$
2,294


$
(550
)

$
(52
)

$


$
(46
)

$
39,580


$
37


$
39,617

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Balance at December 31, 2015
688

 
$
1

 
$
37,968

 
$
2,564

 
$
(692
)
 
$
(50
)
 
$
(3
)
 
$
(61
)
 
$
39,727

 
$
44

 
$
39,771

Net income

 

 

 
1,203

 

 

 

 

 
1,203

 
8

 
1,211

Other comprehensive income (loss)

 

 

 

 
103

 
(23
)
 
7

 
2

 
89

 
4

 
93

Common stock issuances, including dividend reinvestment and employee benefits
1

 

 
16

 

 

 

 

 

 
16

 

 
16

Common stock dividends

 

 

 
(1,140
)
 

 

 

 

 
(1,140
)
 

 
(1,140
)
Distributions to noncontrolling interest in subsidiaries

 

 

 

 

 

 

 

 

 
(3
)
 
(3
)
Balance at June 30, 2016
689


$
1


$
37,984


$
2,627


$
(589
)

$
(73
)

$
4


$
(59
)

$
39,895


$
53


$
39,948

(a)
The $18 million change in Noncontrolling Interests is primarily related to an acquisition of majority interest in a solar company for an insignificant amount of cash consideration.

See Notes to Condensed Consolidated Financial Statements
10


PART I


DUKE ENERGY CAROLINAS, LLC
Condensed Consolidated Statements of Operations and Comprehensive Income
(Unaudited)
 
Three Months Ended
 
Six Months Ended
 
June 30,
 
June 30,
(in millions)
2016

 
2015

 
2016

 
2015

Operating Revenues
$
1,675

 
$
1,707

 
$
3,415

 
$
3,608

Operating Expenses
 
 
 
 
 
 
 
Fuel used in electric generation and purchased power
389

 
427

 
810

 
1,005

Operation, maintenance and other
476

 
469

 
988

 
958

Depreciation and amortization
275

 
261

 
534

 
510

Property and other taxes
71

 
67

 
138

 
137

Total operating expenses
1,211

 
1,224

 
2,470

 
2,610

Operating Income
464

 
483

 
945

 
998

Other Income and Expenses, net
45

 
41

 
82

 
83

Interest Expense
107

 
106

 
214

 
208

Income Before Income Taxes
402

 
418

 
813

 
873

Income Tax Expense
141

 
153

 
281

 
316

Net Income
$
261

 
$
265

 
$
532

 
$
557

Other Comprehensive Income, net of tax
 
 
 
 
 
 
 
Reclassification into earnings from cash flow hedges

 

 
1

 

Comprehensive Income
$
261

 
$
265

 
$
533

 
$
557



See Notes to Condensed Consolidated Financial Statements
11


PART I

DUKE ENERGY CAROLINAS, LLC
Condensed Consolidated Balance Sheets
(Unaudited)
(in millions)
June 30, 2016

 
December 31, 2015

ASSETS
 
 
 
Current Assets
 
 
 
Cash and cash equivalents
$
16

 
$
13

Receivables (net of allowance for doubtful accounts of $2 at 2016 and $3 at 2015)
112

 
142

Receivables of VIEs (net of allowance for doubtful accounts of $7 at 2016 and 2015)
696

 
596

Receivables from affiliated companies
71

 
107

Notes receivable from affiliated companies
252

 
163

Inventory
1,169

 
1,276

Regulatory assets
262

 
305

Other
86

 
128

Total current assets
2,664

 
2,730

Investments and Other Assets
 
 
 
Nuclear decommissioning trust funds
3,133

 
3,050

Other
916

 
999

Total investments and other assets
4,049

 
4,049

Property, Plant and Equipment
 
 
 
Cost
40,285

 
39,398

Accumulated depreciation and amortization
(13,880
)
 
(13,521
)
Net property, plant and equipment
26,405

 
25,877

Regulatory Assets and Deferred Debits
 
 
 
Regulatory assets
2,856

 
2,766

Other
3

 
4

Total regulatory assets and deferred debits
2,859

 
2,770

Total Assets
$
35,977

 
$
35,426

LIABILITIES AND EQUITY
 
 
 
Current Liabilities
 
 
 
Accounts payable
$
565

 
$
753

Accounts payable to affiliated companies
173

 
229

Taxes accrued
137

 
25

Interest accrued
108

 
95

Current maturities of long-term debt
468

 
356

Regulatory liabilities
91

 
39

Other
400

 
519

Total current liabilities
1,942


2,016

Long-Term Debt
8,592

 
7,711

Long-Term Debt Payable to Affiliated Companies
300

 
300

Deferred Credits and Other Liabilities
 
 
 
Deferred income taxes
6,472

 
6,146

Investment tax credits
196

 
199

Accrued pension and other post-retirement benefit costs
96

 
107

Asset retirement obligations
3,910

 
3,918

Regulatory liabilities
2,885

 
2,802

Other
645

 
621

Total deferred credits and other liabilities
14,204

 
13,793

Commitments and Contingencies


 


Equity
 
 
 
Member's equity
10,949

 
11,617

Accumulated other comprehensive loss
(10
)
 
(11
)
Total equity
10,939

 
11,606

Total Liabilities and Equity
$
35,977

 
$
35,426


See Notes to Condensed Consolidated Financial Statements
12


PART I

DUKE ENERGY CAROLINAS, LLC
Condensed Consolidated Statements of Cash Flows
(Unaudited)
 
Six Months Ended
 
June 30,
(in millions)
2016

 
2015

CASH FLOWS FROM OPERATING ACTIVITIES
 
 
 
Net income
$
532

 
$
557

Adjustments to reconcile net income to net cash provided by operating activities:
 
 
 
Depreciation and amortization (including amortization of nuclear fuel)
673

 
670

Equity component of AFUDC
(48
)
 
(48
)
Deferred income taxes
273

 
184

Accrued pension and other post-retirement benefit costs
2

 
7

Contributions to qualified pension plans

 
(42
)
Payments for asset retirement obligations
(118
)
 
(60
)
(Increase) decrease in
 
 
 
Net realized and unrealized mark-to-market and hedging transactions
3

 

Receivables
(48
)
 
45

Receivables from affiliated companies
36

 
(31
)
Inventory
102

 
(31
)
Other current assets
24

 
34

Increase (decrease) in
 
 
 
Accounts payable
(226
)
 
(200
)
Accounts payable to affiliated companies
(56
)
 
(13
)
Taxes accrued
188

 
73

Other current liabilities
28

 
(33
)
Other assets
22

 
58

Other liabilities
(14
)
 
(49
)
Net cash provided by operating activities
1,373

 
1,121

CASH FLOWS FROM INVESTING ACTIVITIES
 
 
 
Capital expenditures
(1,031
)
 
(954
)
Purchases of available-for-sale securities
(1,395
)
 
(1,410
)
Proceeds from sales and maturities of available-for-sale securities
1,395

 
1,410

Notes receivable from affiliated companies
(89
)
 
(550
)
Other
(41
)
 
8

Net cash used in investing activities
(1,161
)
 
(1,496
)
CASH FLOWS FROM FINANCING ACTIVITIES
 
 
 
Proceeds from the issuance of long-term debt
992

 
496

Payments for the redemption of long-term debt
(1
)
 

Distributions to parent
(1,200
)
 
(100
)
Other

 
(6
)
Net cash (used in) provided by financing activities
(209
)
 
390

Net increase in cash and cash equivalents
3

 
15

Cash and cash equivalents at beginning of period
13

 
13

Cash and cash equivalents at end of period
$
16

 
$
28

Supplemental Disclosures:
 
 
 
Significant non-cash transactions:
 
 
 
Accrued capital expenditures
$
228

 
$
160


See Notes to Condensed Consolidated Financial Statements
13


PART I

DUKE ENERGY CAROLINAS, LLC
Condensed Consolidated Statements of Changes in Equity
(Unaudited)
 
 
 
Accumulated Other
 
 
 
 
 
Comprehensive Loss
 
 
 
 
 
 
 
Net Unrealized

 
 
 
 
 
Net Losses on

 
Losses on

 
 
 
Member's

 
Cash Flow

 
Available-for-

 
Total

(in millions)
Equity

 
Hedges

 
Sale Securities

 
Equity

Balance at December 31, 2014
$
10,937

 
$
(12
)
 
$
(1
)
 
$
10,924

Net income
557

 

 

 
557

Distributions to parent
(100
)
 

 

 
(100
)
Balance at June 30, 2015
$
11,394

 
$
(12
)
 
$
(1
)
 
$
11,381

 
 
 
 
 
 
 
 
Balance at December 31, 2015
$
11,617

 
$
(11
)
 
$

 
$
11,606

Net income
532

 

 

 
532

Other comprehensive income

 
1

 

 
1

Distributions to parent
(1,200
)
 

 

 
(1,200
)
Balance at June 30, 2016
$
10,949

 
$
(10
)
 
$

 
$
10,939



See Notes to Condensed Consolidated Financial Statements
14


PART I


PROGRESS ENERGY, INC.
Condensed Consolidated Statements of Operations and Comprehensive Income
(Unaudited)
 
Three Months Ended
 
Six Months Ended
 
June 30,
 
June 30,
(in millions)
2016

 
2015

 
2016

 
2015

Operating Revenues
$
2,348

 
$
2,476

 
$
4,680

 
$
5,012

Operating Expenses
 
 
 
 
 
 
 
Fuel used in electric generation and purchased power
852

 
1,003

 
1,712

 
2,035

Operation, maintenance and other
525

 
568

 
1,117

 
1,133

Depreciation and amortization
296

 
283

 
586

 
570

Property and other taxes
120

 
124

 
239

 
235

Impairment charges
1

 

 
3

 

Total operating expenses
1,794

 
1,978

 
3,657

 
3,973

Gains on Sales of Other Assets and Other, net
6

 
6

 
12

 
14

Operating Income
560

 
504

 
1,035

 
1,053

Other Income and Expenses, net
28

 
19

 
48

 
46

Interest Expense
160

 
166

 
320

 
334

Income From Continuing Operations Before Income Taxes
428

 
357

 
763

 
765

Income Tax Expense From Continuing Operations
154

 
140

 
277

 
284

Income From Continuing Operations
274

 
217

 
486

 
481

Loss From Discontinued Operations, net of tax

 

 

 
(1
)
Net Income
274

 
217

 
486

 
480

Less: Net Income Attributable to Noncontrolling Interests
2

 
2

 
5

 
5

Net Income Attributable to Parent
$
272

 
$
215

 
$
481

 
$
475

 
 
 
 
 
 
 
 
Net Income
$
274

 
$
217

 
$
486

 
$
480

Other Comprehensive Income, net of tax
 
 
 
 
 
 
 
Pension and OPEB adjustments
1

 
1

 
2

 
2

Reclassification into earnings from cash flow hedges
2

 
1

 
3

 
(1
)
Unrealized (losses) gains on available-for-sale securities

 
(1
)
 
1

 
(1
)
Other Comprehensive Income, net of tax
3


1


6



Comprehensive Income
277

 
218

 
492

 
480

Less: Comprehensive Income Attributable to Noncontrolling Interests
2

 
2

 
5

 
5

Comprehensive Income Attributable to Parent
$
275


$
216


$
487


$
475



See Notes to Condensed Consolidated Financial Statements
15


PART I

PROGRESS ENERGY, INC.
Condensed Consolidated Balance Sheets
(Unaudited)
(in millions)
June 30, 2016

 
December 31, 2015

ASSETS
 
 
 
Current Assets
 
 
 
Cash and cash equivalents
$
34

 
$
44

Receivables (net of allowance for doubtful accounts of $6 at 2016 and 2015)
100

 
151

Receivables of VIEs (net of allowance for doubtful accounts of $8 at 2016 and 2015)
776

 
658

Receivables from affiliated companies
11

 
375

Inventory
1,725

 
1,751

Regulatory assets (includes $34 related to VIEs at 2016)
322

 
362

Other
168

 
156

Total current assets
3,136

 
3,497

Investments and Other Assets
 
 
 
Nuclear decommissioning trust funds
2,834

 
2,775

Goodwill
3,655

 
3,655

Other
852

 
834

Total investments and other assets
7,341

 
7,264

Property, Plant and Equipment
 
 
 
Cost
43,720

 
42,666

Accumulated depreciation and amortization
(15,087
)
 
(14,867
)
Generation facilities to be retired, net
506

 
548

Net property, plant and equipment
29,139

 
28,347

Regulatory Assets and Deferred Debits
 
 
 
Regulatory assets (includes $1,194 related to VIEs at 2016)
5,298

 
5,435

Other
4

 
5

Total regulatory assets and deferred debits
5,302

 
5,440

Total Assets
$
44,918

 
$
44,548

LIABILITIES AND EQUITY
 
 
 
Current Liabilities
 
 
 
Accounts payable
$
690

 
$
722

Accounts payable to affiliated companies
232

 
311

Notes payable to affiliated companies
916

 
1,308

Taxes accrued
162

 
53

Interest accrued
185

 
195

Current maturities of long-term debt (includes $35 related to VIEs at 2016)
300

 
315

Regulatory liabilities
166

 
286

Other
702

 
891

Total current liabilities
3,353

 
4,081

Long-Term Debt (includes $1,768 at 2016 and $479 at 2015 related to VIEs)
15,036

 
13,999

Long-Term Debt Payable to Affiliated Companies
150

 
150

Deferred Credits and Other Liabilities
 
 
 
Deferred income taxes
5,044

 
4,790

Accrued pension and other post-retirement benefit costs
519

 
536

Asset retirement obligations
5,386

 
5,369

Regulatory liabilities
2,409

 
2,387

Other
328

 
383

Total deferred credits and other liabilities
13,686

 
13,465

Commitments and Contingencies

 

Equity
 
 
 
Common stock, $0.01 par value, 100 shares authorized and outstanding at 2016 and 2015

 

Additional paid-in capital
8,092

 
8,092

Retained earnings
4,661

 
4,831

Accumulated other comprehensive loss
(42
)
 
(48
)
Total Progress Energy, Inc. stockholders' equity
12,711

 
12,875

Noncontrolling interests
(18
)
 
(22
)
Total equity
12,693

 
12,853

Total Liabilities and Equity
$
44,918

 
$
44,548


See Notes to Condensed Consolidated Financial Statements
16


PART I

PROGRESS ENERGY, INC.
Condensed Consolidated Statements of Cash Flows
(Unaudited)
 
Six Months Ended
 
June 30,
(in millions)
2016

 
2015

CASH FLOWS FROM OPERATING ACTIVITIES
 
 
 
Net income
$
486

 
$
480

Adjustments to reconcile net income to net cash provided by operating activities:
 
 
 
Depreciation, amortization and accretion (including amortization of nuclear fuel)
696

 
648

Equity component of AFUDC
(30
)
 
(26
)
Gains on sales of other assets
(15
)
 
(14
)
Impairment charges
3

 

Deferred income taxes
285

 
358

Accrued pension and other post-retirement benefit costs
(12
)
 
(3
)
Contributions to qualified pension plans

 
(42
)
Payments for asset retirement obligations
(126
)
 
(61
)
(Increase) decrease in
 
 
 
Net realized and unrealized mark-to-market and hedging transactions
32

 
5

Receivables
(66
)
 
(103
)
Receivables from affiliated companies
306

 
(55
)
Inventory
25

 
62

Other current assets
45

 
215

Increase (decrease) in
 
 
 
Accounts payable
(26
)
 
(182
)
Accounts payable to affiliated companies
(79
)
 
68

Taxes accrued
90

 
94

Other current liabilities
(162
)
 
(9
)
Other assets
(72
)
 
(70
)
Other liabilities
15

 
(32
)
Net cash provided by operating activities
1,395

 
1,333

CASH FLOWS FROM INVESTING ACTIVITIES
 
 
 
Capital expenditures
(1,441
)
 
(1,170
)
Purchases of available-for-sale securities
(1,570
)
 
(562
)
Proceeds from sales and maturities of available-for-sale securities
1,594

 
624

Proceeds from insurance
58

 

Notes receivable from affiliated companies

 
220

Change in restricted cash
(6
)
 

Other
(14
)
 
4

Net cash used in investing activities
(1,379
)
 
(884
)
CASH FLOWS FROM FINANCING ACTIVITIES
 
 
 
Proceeds from the issuance of long-term debt
1,338

 

Payments for the redemption of long-term debt
(320
)
 
(549
)
Notes payable to affiliated companies
(392
)
 
110

Distributions to noncontrolling interests
(1
)
 
(4
)
Dividends to parent
(651
)
 

Other

 
(3
)
Net cash used in financing activities
(26
)
 
(446
)
Net (decrease) increase in cash and cash equivalents
(10
)
 
3

Cash and cash equivalents at beginning of period
44

 
42

Cash and cash equivalents at end of period
$
34

 
$
45

Supplemental Disclosures:
 
 
 
Significant non-cash transactions:
 
 
 
Accrued capital expenditures
$
288

 
$
271


See Notes to Condensed Consolidated Financial Statements
17


PART I

PROGRESS ENERGY, INC.
Condensed Consolidated Statements of Changes in Equity
(Unaudited)
 
 
 
 
 
 
 
Accumulated Other Comprehensive Loss
 
 
 
 
 
 
 
 
 
 
 
 
 
Net

 
Net Unrealized

 
 
 
Total Progress

 
 
 
 
 
 
 
Additional

 
 
 
Losses on

 
Gains on

 
Pension and

 
Energy, Inc.

 
 
 
 
 
Common

 
Paid-in

 
Retained

 
Cash Flow

 
Available-for-

 
OPEB

 
Stockholders'

 
Noncontrolling

 
Total

(in millions)
Stock

 
Capital

 
Earnings

 
Hedges

 
Sale Securities

 
Adjustments

 
Equity

 
Interests

 
Equity

Balance at December 31, 2014
$

 
$
7,467

 
$
3,782

 
$
(35
)
 
$
1

 
$
(7
)
 
$
11,208

 
$
(32
)
 
$
11,176

Net income

 

 
475

 

 

 

 
475

 
5

 
480

Other comprehensive (loss) income

 

 

 
(1
)
 
(1
)
 
2

 

 

 

Distributions to noncontrolling interests

 

 

 

 

 

 

 
(4
)
 
(4
)
Other

 

 
(2
)
 

 

 

 
(2
)
 
4

 
2

Balance at June 30, 2015
$


$
7,467


$
4,255


$
(36
)

$


$
(5
)

$
11,681


$
(27
)

$
11,654

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Balance at December 31, 2015
$

 
$
8,092

 
$
4,831

 
$
(31
)
 
$

 
$
(17
)
 
$
12,875

 
$
(22
)
 
$
12,853

Net income

 

 
481

 

 

 

 
481

 
5

 
486

Other comprehensive income

 

 

 
3

 
1

 
2

 
6

 

 
6

Distributions to noncontrolling interests

 

 

 

 

 

 

 
(1
)
 
(1
)
Dividends to parent

 

 
(651
)
 

 

 

 
(651
)
 

 
(651
)
Balance at June 30, 2016
$


$
8,092


$
4,661


$
(28
)

$
1


$
(15
)

$
12,711


$
(18
)

$
12,693



See Notes to Condensed Consolidated Financial Statements
18


PART I


DUKE ENERGY PROGRESS, LLC
Condensed Consolidated Statements of Operations and Comprehensive Income
(Unaudited)
 
Three Months Ended
 
Six Months Ended
 
June 30,
 
June 30,
(in millions)
2016

 
2015

 
2016

 
2015

Operating Revenues
$
1,213

 
$
1,193

 
$
2,520

 
$
2,642

Operating Expenses
 
 
 
 
 
 
 
Fuel used in electric generation and purchased power
424

 
449

 
872

 
1,024

Operation, maintenance and other
321

 
362

 
707

 
737

Depreciation and amortization
175

 
163

 
350

 
315

Property and other taxes
38

 
35

 
79

 
67

Total operating expenses
958

 
1,009

 
2,008

 
2,143

Gains on Sales of Other Assets and Other, net

 

 
1

 
1

Operating Income
255

 
184

 
513

 
500

Other Income and Expenses, net
12

 
15

 
29

 
35

Interest Expense
64

 
56

 
127

 
116

Income Before Income Taxes
203

 
143

 
415

 
419

Income Tax Expense
72

 
58

 
147

 
151

Net Income and Comprehensive Income
$
131

 
$
85

 
$
268

 
$
268



See Notes to Condensed Consolidated Financial Statements
19


PART I

DUKE ENERGY PROGRESS, LLC
Condensed Consolidated Balance Sheets
(Unaudited)
(in millions)
June 30, 2016

 
December 31, 2015

ASSETS
 
 
 
Current Assets
 
 
 
Cash and cash equivalents
$
8

 
$
15

Receivables (net of allowance for doubtful accounts of $4 at 2016 and 2015)
35

 
87

Receivables of VIEs (net of allowance for doubtful accounts of $5 at 2016 and 2015)
421

 
349

Receivables from affiliated companies
9

 
16

Inventory
1,068

 
1,088

Regulatory assets
187

 
264

Other
35

 
121

Total current assets
1,763

 
1,940

Investments and Other Assets
 
 
 
Nuclear decommissioning trust funds
2,110

 
2,035

Other
509

 
486

Total investments and other assets
2,619

 
2,521

Property, Plant and Equipment
 
 
 
Cost
27,771

 
27,313

Accumulated depreciation and amortization
(10,350
)
 
(10,141
)
Generation facilities to be retired, net
506

 
548

Net property, plant and equipment
17,927

 
17,720

Regulatory Assets and Deferred Debits
 
 
 
Regulatory assets
2,744

 
2,710

Other
2

 
3

Total regulatory assets and deferred debits
2,746

 
2,713

Total Assets
$
25,055

 
$
24,894

LIABILITIES AND EQUITY
 
 
 
Current Liabilities
 
 
 
Accounts payable
$
300

 
$
399

Accounts payable to affiliated companies
134

 
190

Notes payable to affiliated companies
78

 
209

Taxes accrued
71

 
15

Interest accrued
96

 
96

Current maturities of long-term debt
252

 
2

Regulatory liabilities
84

 
85

Other
314

 
412

Total current liabilities
1,329

 
1,408

Long-Term Debt
6,163

 
6,366

Long-Term Debt Payable to Affiliated Companies
150

 
150

Deferred Credits and Other Liabilities
 
 
 
Deferred income taxes
3,167

 
3,027

Investment tax credits
152

 
132

Accrued pension and other post-retirement benefit costs
249

 
262

Asset retirement obligations
4,594

 
4,567

Regulatory liabilities
1,901

 
1,878

Other
23

 
45

Total deferred credits and other liabilities
10,086

 
9,911

Commitments and Contingencies

 

Equity
 
 
 
Member's Equity
7,327

 
7,059

Total equity
7,327

 
7,059

Total Liabilities and Equity
$
25,055

 
$
24,894


See Notes to Condensed Consolidated Financial Statements
20


PART I

DUKE ENERGY PROGRESS, LLC
Condensed Consolidated Statements of Cash Flows
(Unaudited)
 
Six Months Ended
 
June 30,
(in millions)
2016

 
2015

CASH FLOWS FROM OPERATING ACTIVITIES
 
 
 
Net income
$
268

 
$
268

Adjustments to reconcile net income to net cash provided by operating activities:
 
 
 
Depreciation, amortization and accretion (including amortization of nuclear fuel)
451

 
389

Equity component of AFUDC
(20
)
 
(23
)
Gains on sales of other assets
(3
)
 
(1
)
Deferred income taxes
172

 
177

Accrued pension and other post-retirement benefit costs
(16
)
 
(7
)
Contributions to qualified pension plans

 
(21
)
Payments for asset retirement obligations
(100
)
 
(32
)
(Increase) decrease in
 
 
 
Net realized and unrealized mark-to-market and hedging transactions
(1
)
 
(3
)
Receivables
(19
)
 
(64
)
Receivables from affiliated companies
7

 
6

Inventory
20

 
53

Other current assets
131

 
156

Increase (decrease) in
 
 
 
Accounts payable
(28
)
 
(128
)
Accounts payable to affiliated companies
(56
)
 
62

Taxes accrued
56

 
66

Other current liabilities
(12
)
 
(15
)
Other assets
(26
)
 
(31
)
Other liabilities
(6
)
 
(21
)
Net cash provided by operating activities
818

 
831

CASH FLOWS FROM INVESTING ACTIVITIES
 
 
 
Capital expenditures
(704
)
 
(699
)
Purchases of available-for-sale securities
(1,299
)
 
(319
)
Proceeds from sales and maturities of available-for-sale securities
1,284

 
301

Notes receivable from affiliated companies

 
237

Other
(19
)
 
6

Net cash used in investing activities
(738
)
 
(474
)
CASH FLOWS FROM FINANCING ACTIVITIES
 
 
 
Proceeds from the issuance of long-term debt
59

 

Payments for the redemption of long-term debt
(15
)
 
(544
)
Notes payable to affiliated companies
(131
)
 
192

Other

 
(1
)
Net cash used in financing activities
(87
)
 
(353
)
Net (decrease) increase in cash and cash equivalents
(7
)
 
4

Cash and cash equivalents at beginning of period
15

 
9

Cash and cash equivalents at end of period
$
8

 
$
13

Supplemental Disclosures:
 
 
 
Significant non-cash transactions:
 
 
 
Accrued capital expenditures
$
73

 
$
135


See Notes to Condensed Consolidated Financial Statements
21


PART I

DUKE ENERGY PROGRESS, LLC
Condensed Consolidated Statements of Changes in Equity
(Unaudited)
 
Common

 
Retained

 
Member's

 
Total

(in millions)
Stock

 
Earnings

 
Equity

 
Equity

Balance at December 31, 2014
$
2,159

 
$
3,708

 
$

 
$
5,867

Net income

 
268

 

 
268

Balance at June 30, 2015
$
2,159

 
$
3,976

 
$

 
$
6,135

 
 
 
 
 
 
 
 
Balance at December 31, 2015
$

 
$

 
$
7,059

 
$
7,059

Net income

 

 
268

 
268

Balance at June 30, 2016
$

 
$

 
$
7,327

 
$
7,327



See Notes to Condensed Consolidated Financial Statements
22


PART I


DUKE ENERGY FLORIDA, LLC
Condensed Consolidated Statements of Operations and Comprehensive Income
(Unaudited)
 
Three Months Ended
 
Six Months Ended
 
June 30,
 
June 30,
(in millions)
2016

 
2015

 
2016

 
2015

Operating Revenues
$
1,133

 
$
1,281

 
$
2,157

 
$
2,367

Operating Expenses
 
 
 
 
 
 
 
Fuel used in electric generation and purchased power
429

 
554

 
841

 
1,011

Operation, maintenance and other
199

 
202

 
404

 
390

Depreciation and amortization
122

 
122

 
236

 
256

Property and other taxes
82

 
88

 
160

 
168

Impairment charges
1

 

 
3

 

Total operating expenses
833

 
966

 
1,644

 
1,825

Operating Income
300

 
315

 
513

 
542

Other Income and Expenses, net
14

 
4

 
19

 
10

Interest Expense
40

 
50

 
81

 
99

Income Before Income Taxes
274

 
269

 
451

 
453

Income Tax Expense
103

 
104

 
170

 
175

Net Income
$
171

 
$
165

 
$
281

 
$
278

Other Comprehensive Income, net of tax
 
 
 
 
 
 
 
Unrealized gains on investments in available-for-sale securities

 
$

 
1

 

Comprehensive Income
$
171

 
$
165

 
$
282


$
278



See Notes to Condensed Consolidated Financial Statements
23


PART I

DUKE ENERGY FLORIDA, LLC
Condensed Consolidated Balance Sheets
(Unaudited)
(in millions)
June 30, 2016

 
December 31, 2015

ASSETS
 
 
 
Current Assets
 
 
 
Cash and cash equivalents
$
8

 
$
8

Receivables (net of allowance for doubtful accounts of $2 at 2016 and 2015)
64

 
60

Receivables of VIEs (net of allowance for doubtful accounts of $3 at 2016 and 2015)
355

 
308

Receivables from affiliated companies
3

 
84

Inventory
657

 
663

Regulatory assets (includes $34 related to VIEs at 2016)
135

 
98

Other
43

 
21

Total current assets
1,265

 
1,242

Investments and Other Assets
 
 
 
Nuclear decommissioning trust funds
724

 
740

Other
288

 
292

Total investments and other assets
1,012

 
1,032

Property, Plant and Equipment
 
 
 
Cost
15,938

 
15,343

Accumulated depreciation and amortization
(4,730
)
 
(4,720
)
Net property, plant and equipment
11,208

 
10,623

Regulatory Assets and Deferred Debits
 
 
 
Regulatory assets (includes $1,194 related to VIEs at 2016)
2,553

 
2,725

Other
3

 
2

Total regulatory assets and deferred debits
2,556

 
2,727

Total Assets
$
16,041

 
$
15,624

LIABILITIES AND EQUITY
 
 
 
Current Liabilities
 
 
 
Accounts payable
$
390

 
$
322

Accounts payable to affiliated companies
100

 
116

Notes payable to affiliated companies
406

 
813

Taxes accrued
156

 
132

Interest accrued
40

 
43

Current maturities of long-term debt (includes $35 related to VIEs at 2016)
48

 
13

Regulatory liabilities
82

 
200

Other
361

 
452

Total current liabilities
1,583

 
2,091

Long-Term Debt (includes $1,468 at 2016 and $225 at 2015 related to VIEs)
5,492

 
4,253

Deferred Credits and Other Liabilities
 
 
 
Deferred income taxes
2,571

 
2,460

Accrued pension and other post-retirement benefit costs
238

 
242

Asset retirement obligations
792

 
802

Regulatory liabilities
508

 
509

Other
103

 
146

Total deferred credits and other liabilities
4,212

 
4,159

Commitments and Contingencies

 

Equity
 
 
 
Member's equity
4,753

 
5,121

Accumulated other comprehensive income
1

 

Total equity
4,754

 
5,121

Total Liabilities and Equity
$
16,041

 
$
15,624


See Notes to Condensed Consolidated Financial Statements
24


PART I

DUKE ENERGY FLORIDA, LLC
Condensed Consolidated Statements of Cash Flows
(Unaudited)
 
Six Months Ended
 
June 30,
(in millions)
2016

 
2015

CASH FLOWS FROM OPERATING ACTIVITIES
 
 
 
Net income
$
281

 
$
278

Adjustments to reconcile net income to net cash provided by operating activities:
 
 
 
Depreciation, amortization and accretion
239

 
258

Equity component of AFUDC
(9
)
 
(2
)
Impairment charges
3

 

Deferred income taxes
113

 
237

Accrued pension and other post-retirement benefit costs
1

 
3

Contributions to qualified pension plans

 
(21
)
Payments for asset retirement obligations
(25
)
 
(28
)
(Increase) decrease in
 
 
 
Net realized and unrealized mark-to-market and hedging transactions
34

 
5

Receivables
(49
)
 
(40
)
Receivables from affiliated companies
23

 
(53
)
Inventory
5

 
10

Other current assets
(13
)
 
10

Increase (decrease) in
 
 
 
Accounts payable
3

 
(53
)
Accounts payable to affiliated companies
(16
)
 
3

Taxes accrued
5

 
65

Other current liabilities
(142
)
 
5

Other assets
(47
)
 
(44
)
Other liabilities
20

 
(19
)
Net cash provided by operating activities
426

 
614

CASH FLOWS FROM INVESTING ACTIVITIES
 
 
 
Capital expenditures
(737
)
 
(471
)
Purchases of available-for-sale securities
(271
)
 
(243
)
Proceeds from sales and maturities of available-for-sale securities
310

 
323

Proceeds from insurance
58

 

Change in restricted cash
(6
)
 

Other
5

 
1

Net cash used in investing activities
(641
)
 
(390
)
CASH FLOWS FROM FINANCING ACTIVITIES
 
 
 
Proceeds from the issuance of long-term debt
1,278

 

Payments for the redemption of long-term debt
(5
)
 
(5
)
Notes payable to affiliated companies
(407
)
 
137

Dividends to parent

 
(350
)
Distributions to parent
(649
)
 

Other
(2
)
 
(1
)
Net cash provided by (used in) financing activities
215

 
(219
)
Net increase in cash and cash equivalents

 
5

Cash and cash equivalents at beginning of period
8

 
8

Cash and cash equivalents at end of period
$
8

 
$
13

Supplemental Disclosures:
 
 
 
Significant non-cash transactions:
 
 
 
Accrued capital expenditures
$
215

 
$
136


See Notes to Condensed Consolidated Financial Statements
25


PART I

DUKE ENERGY FLORIDA, LLC
Condensed Consolidated Statements of Changes in Equity
(Unaudited)
 
 
 
 
 
 
 
Accumulated
 
 
 
 
 
 
 
 
 
Other
 
 
 
 
 
 
 
 
 
Comprehensive
 
 
 
 
 
 
 
 
 
Income
 
 
 
 
 
 
 
 
 
Net Unrealized

 
 
 
 
 
 
 
 
 
Gains on

 
 
 
Common

 
Retained

 
Member's

 
Available-for-Sale

 
Total

(in millions)
Stock

 
Earnings

 
Equity

 
Securities

 
Equity

Balance at December 31, 2014
$
1,762

 
$
3,460

 
$

 
$

 
$
5,222

Net income

 
278

 

 

 
278

Dividends to parent

 
(350
)
 

 

 
(350
)
Balance at June 30, 2015
$
1,762

 
$
3,388

 
$

 
$

 
$
5,150

 
 
 
 
 
 
 
 
 
 
Balance at December 31, 2015
$

 
$

 
$
5,121

 
$

 
$
5,121

Net income

 

 
281

 

 
281

Other comprehensive income

 

 

 
1

 
1

Distributions to parent

 

 
(649
)
 

 
(649
)
Balance at June 30, 2016
$

 
$

 
$
4,753

 
$
1

 
$
4,754


See Notes to Condensed Consolidated Financial Statements
26


PART I


DUKE ENERGY OHIO, INC.
Condensed Consolidated Statements of Operations and Comprehensive Income
(Unaudited)
 
Three Months Ended
 
Six Months Ended
 
June 30,
 
June 30,
(in millions)
2016

 
2015

 
2016


2015

Operating Revenues
 
 
 
 
 
 
 
Regulated electric
$
323

 
$
299

 
$
663

 
$
638

Nonregulated electric and other
6

 
9

 
12

 
23

Regulated natural gas
99

 
97

 
269

 
330

Total operating revenues
428

 
405

 
944

 
991

Operating Expenses
 
 
 
 
 
 
 
Fuel used in electric generation and purchased power – regulated
100

 
107

 
211

 
222

Fuel used in electric generation and purchased power – nonregulated
13

 
12

 
23

 
26

Cost of natural gas
9

 
12

 
58

 
109

Operation, maintenance and other
122

 
118

 
241

 
246

Depreciation and amortization
64

 
58

 
125

 
115

Property and other taxes
65

 
57

 
136

 
127

Total operating expenses
373

 
364

 
794

 
845

Gains on Sales of Other Assets and Other, net

 
2

 
1

 
8

Operating Income
55

 
43

 
151

 
154

Other Income and Expenses, net
1

 
(5
)
 
3

 
(2
)
Interest Expense
21

 
18

 
41

 
38

Income From Continuing Operations Before Income Taxes
35

 
20

 
113

 
114

Income Tax Expense From Continuing Operations
12

 
7

 
33

 
42

Income From Continuing Operations
23

 
13

 
80

 
72

Income (Loss) From Discontinued Operations, net of tax

 
(65
)
 
2

 
25

Net Income (Loss) and Comprehensive Income (Loss)
$
23

 
$
(52
)
 
$
82

 
$
97



See Notes to Condensed Consolidated Financial Statements
27


PART I

DUKE ENERGY OHIO, INC.
Condensed Consolidated Balance Sheets
(Unaudited)
(in millions)
June 30, 2016

 
December 31, 2015

ASSETS
 
 
 
Current Assets
 
 
 
Cash and cash equivalents
$
10

 
$
14

Receivables (net of allowance for doubtful accounts of $2 at 2016 and 2015)
63

 
66

Receivables from affiliated companies
35

 
84

Notes receivable from affiliated companies
186

 

Inventory
110

 
105

Regulatory assets
54

 
36

Other
65

 
110

Total current assets
523

 
415

Investments and Other Assets
 
 
 
Goodwill
920

 
920

Other
16

 
20

Total investments and other assets
936

 
940

Property, Plant and Equipment
 
 
 
Cost
7,906

 
7,750

Accumulated depreciation and amortization
(2,536
)
 
(2,507
)
Net property, plant and equipment
5,370

 
5,243

Regulatory Assets and Deferred Debits
 
 
 
Regulatory assets
472

 
497

Other
2

 
2

Total regulatory assets and deferred debits
474

 
499

Total Assets
$
7,303

 
$
7,097

LIABILITIES AND EQUITY
 
 
 
Current Liabilities
 
 
 
Accounts payable
$
218

 
$
207

Accounts payable to affiliated companies
76

 
53

Notes payable to affiliated companies

 
103

Taxes accrued
108

 
171

Interest accrued
19

 
18

Current maturities of long-term debt
54

 
106

Regulatory liabilities
18

 
12

Other
82

 
153

Total current liabilities
575

 
823

Long-Term Debt
1,808

 
1,467

Long-Term Debt Payable to Affiliated Companies
25

 
25

Deferred Credits and Other Liabilities
 
 
 
Deferred income taxes
1,476

 
1,407

Accrued pension and other post-retirement benefit costs
52

 
56

Asset retirement obligations
125

 
125

Regulatory liabilities
241

 
245

Other
160

 
165

Total deferred credits and other liabilities
2,054

 
1,998

Commitments and Contingencies

 

Equity
 
 
 
Common stock, $8.50 par value, 120,000,000 shares authorized; 89,663,086 shares outstanding at 2016 and 2015
762

 
762

Additional paid-in capital
2,695

 
2,720

Accumulated deficit
(616
)
 
(698
)
Total equity
2,841

 
2,784

Total Liabilities and Equity
$
7,303

 
$
7,097


See Notes to Condensed Consolidated Financial Statements
28


PART I

DUKE ENERGY OHIO, INC.
Condensed Consolidated Statements of Cash Flows
(Unaudited)
 
Six Months Ended
 
June 30,
(in millions)
2016

 
2015

CASH FLOWS FROM OPERATING ACTIVITIES
 
 
 
Net income
$
82

 
$
97

Adjustments to reconcile net income to net cash provided by operating activities:
 
 
 
Depreciation, amortization and accretion
127

 
117

Equity component of AFUDC
(2
)
 
(2
)
Gains on sales of other assets and other, net
(1
)
 
(8
)
Impairment charges

 
40

Deferred income taxes
68

 
62

Accrued pension and other post-retirement benefit costs
3

 
4

Contributions to qualified pension plans

 
(1
)
Payments for asset retirement obligations
(3
)
 
(1
)
(Increase) decrease in
 
 
 
Net realized and unrealized mark-to-market and hedging transactions
(2
)
 
(12
)
Receivables
3

 
6

Receivables from affiliated companies
49

 
46

Inventory
(5
)
 
3

Other current assets
49

 
32

Increase (decrease) in
 
 
 
Accounts payable
8

 
(12
)
Accounts payable to affiliated companies
23

 
19

Taxes accrued
(68
)
 
(68
)
Other current liabilities
(66
)
 
99

Other assets
(8
)
 
19

Other liabilities
(9
)
 
(52
)
Net cash provided by operating activities
248

 
388

CASH FLOWS FROM INVESTING ACTIVITIES
 
 
 
Capital expenditures
(214
)
 
(166
)
Notes receivable from affiliated companies
(186
)
 
130

Other
(13
)
 
(4
)
Net cash used in investing activities
(413
)
 
(40
)
CASH FLOWS FROM FINANCING ACTIVITIES
 
 
 
Proceeds from the issuance of long-term debt
341

 

Payments for the redemption of long-term debt
(52
)
 
(152
)
Notes payable to affiliated companies
(103
)
 
(193
)
Dividends to parent
(25
)
 

Other

 
(1
)
Net cash provided by (used in) financing activities
161

 
(346
)
Net (decrease) increase in cash and cash equivalents
(4
)
 
2

Cash and cash equivalents at beginning of period
14

 
20

Cash and cash equivalents at end of period
$
10

 
$
22

Supplemental Disclosures:
 
 
 
Significant non-cash transactions:
 
 
 
Accrued capital expenditures
$
30

 
$
19

Distribution of membership interest of Duke Energy SAM, LLC to parent

 
1,912


See Notes to Condensed Consolidated Financial Statements
29


PART I

DUKE ENERGY OHIO, INC.
Condensed Consolidated Statements of Changes in Equity
(Unaudited)
 
 
 
Additional

 
 
 
 
 
Common

 
Paid-in

 
Accumulated

 
Total

(in millions)
Stock

 
Capital

 
Deficit

 
Equity

Balance at December 31, 2014
$
762

 
$
4,782

 
$
(870
)
 
$
4,674

Net Income

 

 
97

 
97

Distribution of membership interest of Duke Energy SAM, LLC to parent

 
(1,912
)
 

 
(1,912
)
Balance at June 30, 2015
$
762

 
$
2,870

 
$
(773
)
 
$
2,859

 
 
 
 
 
 
 
 
Balance at December 31, 2015
$
762

 
$
2,720

 
$
(698
)
 
$
2,784

Net income

 

 
82

 
82

Dividends to parent

 
(25
)
 

 
(25
)
Balance at June 30, 2016
$
762


$
2,695


$
(616
)

$
2,841



See Notes to Condensed Consolidated Financial Statements
30


PART I


DUKE ENERGY INDIANA, LLC
Condensed Consolidated Statements of Operations and Comprehensive Income
(Unaudited)
 
Three Months Ended
 
Six Months Ended
 
June 30,
 
June 30,
(in millions)
2016

 
2015

 
2016

 
2015

Operating Revenues
$
702

 
$
686

 
$
1,416

 
$
1,474

Operating Expenses
 
 
 
 
 
 
 
Fuel used in electric generation and purchased power
220

 
235

 
448

 
529

Operation, maintenance and other
189

 
180

 
351

 
361

Depreciation and amortization
97

 
107

 
222

 
211

Property and other taxes
22

 
19

 
45

 
18

Total operating expenses
528

 
541

 
1,066

 
1,119

Gain on Sale of Other Assets and Other, net


1

 

 
1

Operating Income
174

 
146

 
350

 
356

Other Income and Expenses, net
6

 
4

 
10

 
9

Interest Expense
47

 
43

 
91

 
88

Income Before Income Taxes
133

 
107


269


277

Income Tax Expense
48

 
39

 
89

 
101

Net Income
$
85

 
$
68


$
180


$
176

Other Comprehensive Loss, net of tax
 
 
 
 
 
 
 
Reclassification into earnings from cash flow hedges

 

 
(1
)
 
(1
)
Comprehensive Income
$
85

 
$
68


$
179


$
175



See Notes to Condensed Consolidated Financial Statements
31


PART I

DUKE ENERGY INDIANA, LLC
Condensed Consolidated Balance Sheets
(Unaudited)
(in millions)
June 30, 2016

 
December 31, 2015

ASSETS
 
 
 
Current Assets
 
 
 
Cash and cash equivalents
$
12

 
$
9

Receivables (net of allowance for doubtful accounts of $1 at 2016 and 2015)
87

 
96

Receivables from affiliated companies
60

 
71

Notes receivable from affiliated companies
147

 
83

Inventory
508

 
570

Regulatory assets
115

 
102

Other
45

 
15

Total current assets
974

 
946

Investments and Other Assets
221

 
212

Property, Plant and Equipment
 
 
 
Cost
13,677

 
14,007

Accumulated depreciation and amortization
(4,219
)
 
(4,484
)
Generation facilities to be retired, net
93

 

Net property, plant and equipment
9,551

 
9,523

Regulatory Assets and Deferred Debits
 
 
 
Regulatory assets
825

 
716

Other
2

 
2

Total regulatory assets and deferred debits
827

 
718

Total Assets
$
11,573

 
$
11,399

LIABILITIES AND EQUITY
 
 
 
Current Liabilities
 
 
 
Accounts payable
$
146

 
$
189

Accounts payable to affiliated companies
87

 
83

Taxes accrued
40

 
89

Interest accrued
59

 
56

Current maturities of long-term debt
221

 
547

Regulatory liabilities
57

 
62

Other
101

 
97

Total current liabilities
711

 
1,123

Long-Term Debt
3,566

 
3,071

Long-Term Debt Payable to Affiliated Companies
150

 
150

Deferred Credits and Other Liabilities
 
 
 
Deferred income taxes
1,732

 
1,657

Investment tax credits
137

 
138

Accrued pension and other post-retirement benefit costs
74

 
80

Asset retirement obligations
520

 
525

Regulatory liabilities
745

 
754

Other
72

 
65

Total deferred credits and other liabilities
3,280

 
3,219

Commitments and Contingencies

 

Equity
 
 
 
Member's equity
3,866

 

Common stock, no par; $0.01 stated value, 60,000,000 shares authorized; 53,913,701 shares outstanding at 2015

 
1

Additional paid-in capital

 
1,384

Retained earnings

 
2,450

Accumulated other comprehensive income

 
1

Total equity
3,866

 
3,836

Total Liabilities and Equity
$
11,573

 
$
11,399


See Notes to Condensed Consolidated Financial Statements
32


PART I

DUKE ENERGY INDIANA, LLC
Condensed Consolidated Statements of Cash Flows
(Unaudited)
 
Six Months Ended
 
June 30,
(in millions)
2016

 
2015

CASH FLOWS FROM OPERATING ACTIVITIES
 
 
 
Net income
$
180

 
$
176

Adjustments to reconcile net income to net cash provided by operating activities:
 
 
 
Depreciation, amortization and accretion
223

 
214

Equity component of AFUDC
(7
)
 
(6
)
Gain on sale of other assets and other, net

 
(1
)
Deferred income taxes
36

 
232

Accrued pension and other post-retirement benefit costs
4

 
6

Contributions to qualified pension plans

 
(9
)
Payments for asset retirement obligations
(16
)
 
(3
)
(Increase) decrease in
 
 
 
Net realized and unrealized mark-to-market and hedging transactions

 
(2
)
Receivables
12

 
(1
)
Receivables from affiliated companies
11

 
6

Inventory
62

 
(42
)
Other current assets
(19
)
 
87

Increase (decrease) in
 
 
 
Accounts payable
(22
)
 
26

Accounts payable to affiliated companies
4

 
2

Taxes accrued
(42
)
 
(21
)
Other current liabilities
(60
)
 
5

Other assets
(29
)
 
(31
)
Other liabilities
44

 
(43
)
Net cash provided by operating activities
381

 
595

CASH FLOWS FROM INVESTING ACTIVITIES
 
 
 
Capital expenditures
(325
)
 
(380
)
Purchases of available-for-sale securities
(7
)
 
(4
)
Proceeds from sales and maturities of available-for-sale securities
5

 
3

Proceeds from the sales of other assets

 
14

Notes receivable from affiliated companies
(64
)
 
(25
)
Other
(6
)
 
25

Net cash used in investing activities
(397
)
 
(367
)
CASH FLOWS FROM FINANCING ACTIVITIES
 
 
 
Proceeds from the issuance of long-term debt
495

 

Payments for the redemption of long-term debt
(326
)
 

Notes payable to affiliated companies

 
(71
)
Dividends to parent

 
(150
)
Distributions to parent
(149
)
 

Other
(1
)
 
(1
)
Net cash provided by (used in) financing activities
19

 
(222
)
Net increase in cash and cash equivalents
3


6

Cash and cash equivalents at beginning of period
9

 
6

Cash and cash equivalents at end of period
$
12

 
$
12

Supplemental Disclosures:
 
 
 
Significant non-cash transactions:
 
 
 
Accrued capital expenditures
$
43

 
$
46


See Notes to Condensed Consolidated Financial Statements
33


PART I

DUKE ENERGY INDIANA, LLC
Condensed Consolidated Statements of Changes in Equity
(Unaudited)
 
 
 
 
 
 
 
 
 
Accumulated
 
 
 
 
 
 
 
 
 
 
 
Other
 
 
 
 
 
 
 
 
 
 
 
Comprehensive
 
 
 
 
 
 
 
 
 
 
 
Income
 
 
 
 
 
Additional

 
 
 
 
 
Net Gains on

 
 
 
Common

 
Paid-in

 
Retained

 
Member's

 
Cash Flow

 
Total

(in millions)
Stock

 
Capital

 
Earnings

 
Equity

 
Hedges

 
Equity

Balance at December 31, 2014
$
1

 
$
1,384

 
$
2,460

 
$

 
$
3

 
$
3,848

Net income

 

 
176

 

 

 
176

Other comprehensive loss

 

 

 

 
(1
)
 
(1
)
Dividends to parent

 

 
(150
)
 

 

 
(150
)
Balance at June 30, 2015
$
1

 
$
1,384

 
$
2,486


$

 
$
2

 
$
3,873

 
 
 
 
 
 
 
 
 
 
 
 
Balance at December 31, 2015
$
1

 
$
1,384

 
$
2,450

 
$

 
$
1

 
$
3,836

Net income

 

 

 
180

 

 
180

Other comprehensive loss

 

 

 

 
(1
)
 
(1
)
Distributions to parent

 

 

 
(149
)
 

 
(149
)
Transfer to Member's Equity
(1
)
 
(1,384
)
 
(2,450
)
 
3,835

 

 

Balance at June 30, 2016
$

 
$

 
$


$
3,866

 
$

 
$
3,866



See Notes to Condensed Consolidated Financial Statements
34


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements
(Unaudited)


Index to Combined Notes to Condensed Consolidated Financial Statements
The unaudited notes to the condensed consolidated financial statements that follow are a combined presentation. The following list indicates the registrants to which the footnotes apply. Tables within the notes may not sum across due to Progress Energy's consolidation of Duke Energy Progress, Duke Energy Florida and other subsidiaries that are not registrants. In addition, the Duke Energy amounts include balances from subsidiaries that are not registrants.
 
Applicable Notes
Registrant
1
 
2
 
3
 
4
 
5
 
6
 
7
 
8
 
9
 
10
 
11
 
12
 
13
 
14
 
15
 
16
 
17
Duke Energy Corporation
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Duke Energy Carolinas, LLC
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Progress Energy, Inc.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Duke Energy Progress, LLC
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Duke Energy Florida, LLC
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Duke Energy Ohio, Inc.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Duke Energy Indiana, LLC
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
1. ORGANIZATION AND BASIS OF PRESENTATION
NATURE OF OPERATIONS AND BASIS OF CONSOLIDATION
Duke Energy Corporation (collectively with its subsidiaries, Duke Energy) is an energy company headquartered in Charlotte, North Carolina, subject to regulation by the Federal Energy Regulatory Commission (FERC). Duke Energy operates in the United States (U.S.) and Latin America primarily through its direct and indirect subsidiaries. Duke Energy’s subsidiaries include its subsidiary registrants, Duke Energy Carolinas, LLC (Duke Energy Carolinas); Progress Energy, Inc. (Progress Energy); Duke Energy Progress, LLC (Duke Energy Progress); Duke Energy Florida, LLC (Duke Energy Florida); Duke Energy Ohio, Inc. (Duke Energy Ohio) and Duke Energy Indiana, LLC (Duke Energy Indiana, formerly Duke Energy Indiana, Inc.). When discussing Duke Energy’s consolidated financial information, it necessarily includes the results of its six separate subsidiary registrants (collectively referred to as the Subsidiary Registrants), which, along with Duke Energy, are collectively referred to as the Duke Energy Registrants (Duke Energy Registrants).
These Condensed Consolidated Financial Statements include, after eliminating intercompany transactions and balances, the accounts of the Duke Energy Registrants and subsidiaries where the respective Duke Energy Registrants have control. These Condensed Consolidated Financial Statements also reflect the Duke Energy Registrants’ proportionate share of certain jointly owned generation and transmission facilities.
Duke Energy Carolinas is a regulated public utility primarily engaged in the generation, transmission, distribution and sale of electricity in portions of North Carolina and South Carolina. Duke Energy Carolinas is subject to the regulatory provisions of the North Carolina Utilities Commission (NCUC), Public Service Commission of South Carolina (PSCSC), U.S. Nuclear Regulatory Commission (NRC) and FERC. Substantially all of Duke Energy Carolinas’ operations qualify for regulatory accounting.
Progress Energy is a public utility holding company headquartered in Raleigh, North Carolina, subject to regulation by the FERC. Progress Energy conducts operations through its wholly owned subsidiaries, Duke Energy Progress and Duke Energy Florida. Substantially all of Progress Energy’s operations qualify for regulatory accounting.
Duke Energy Progress is a regulated public utility primarily engaged in the generation, transmission, distribution and sale of electricity in portions of North Carolina and South Carolina. Duke Energy Progress is subject to the regulatory provisions of the NCUC, PSCSC, NRC and FERC. Substantially all of Duke Energy Progress’ operations qualify for regulatory accounting.
Duke Energy Florida is a regulated public utility primarily engaged in the generation, transmission, distribution and sale of electricity in portions of Florida. Duke Energy Florida is subject to the regulatory provisions of the Florida Public Service Commission (FPSC), NRC and FERC. Substantially all of Duke Energy Florida’s operations qualify for regulatory accounting.
Duke Energy Ohio is a regulated public utility primarily engaged in the transmission and distribution of electricity in portions of Ohio and Kentucky, the generation and sale of electricity in portions of Kentucky, and the transportation and sale of natural gas in portions of Ohio and Kentucky. Duke Energy Ohio conducts competitive auctions for retail electricity supply in Ohio whereby the energy price is recovered from retail customers and recorded in Operating Revenues on the Condensed Consolidated Statements of Operations and Comprehensive Income. Operations in Kentucky are conducted through its wholly owned subsidiary, Duke Energy Kentucky, Inc. (Duke Energy Kentucky). References herein to Duke Energy Ohio collectively include Duke Energy Ohio and its subsidiaries, unless otherwise noted. Duke Energy Ohio is subject to the regulatory provisions of the Public Utilities Commission of Ohio (PUCO), Kentucky Public Service Commission (KPSC) and FERC. On April 2, 2015, Duke Energy completed the sale of its nonregulated Midwest generation business, which sold power into wholesale energy markets, to a subsidiary of Dynegy Inc. (Dynegy). See Note 2 for additional information. Substantially all of Duke Energy Ohio’s operations that remain after the sale qualify for regulatory accounting.
Duke Energy Indiana is a regulated public utility primarily engaged in the generation, transmission, distribution and sale of electricity in portions of Indiana. Duke Energy Indiana is subject to the regulatory provisions of the Indiana Utility Regulatory Commission (IURC) and FERC. Substantially all of Duke Energy Indiana’s operations qualify for regulatory accounting. On January 1, 2016, Duke Energy Indiana, an Indiana corporation, converted into an Indiana limited liability company.

35


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

BASIS OF PRESENTATION
Duke Energy completed the sale of Duke Energy Ohio's nonregulated Midwest generation business and Duke Energy Retail Sales (collectively, the Disposal Group), a retail sales business owned by Duke Energy, to Dynegy on April 2, 2015. The results of operations of these businesses prior to the date of sale have been classified as Discontinued Operations on the Condensed Consolidated Statements of Operations. Duke Energy has elected to present cash flows of discontinued operations combined with cash flows of continuing operations. Unless otherwise noted, the notes to these Condensed Consolidated Financial Statements exclude amounts related to discontinued operations. See Note 2 for additional information.
These Condensed Consolidated Financial Statements have been prepared in accordance with generally accepted accounting principles (GAAP) in the U.S. for interim financial information and with the instructions to Form 10-Q and Regulation S-X. Accordingly, these Condensed Consolidated Financial Statements do not include all information and notes required by GAAP in the U.S. for annual financial statements. Since the interim Condensed Consolidated Financial Statements and Notes do not include all information and notes required by GAAP in the U.S. for annual financial statements, the Condensed Consolidated Financial Statements and other information included in this quarterly report should be read in conjunction with the Consolidated Financial Statements and Notes in the Duke Energy Registrants’ combined Annual Report on Form 10-K for the year ended December 31, 2015.
The information in these combined notes relates to each of the Duke Energy Registrants as noted in the Index to Combined Notes to Condensed Consolidated Financial Statements. However, none of the registrants make any representations as to information related solely to Duke Energy or the subsidiaries of Duke Energy other than itself.
These Condensed Consolidated Financial Statements, in the opinion of the respective companies’ management, reflect all normal recurring adjustments necessary to fairly present the financial position and results of operations of each of the Duke Energy Registrants. Amounts reported in Duke Energy’s interim Condensed Consolidated Statements of Operations and each of the Subsidiary Registrants’ interim Condensed Consolidated Statements of Operations and Comprehensive Income are not necessarily indicative of amounts expected for the respective annual periods due to effects of seasonal temperature variations on energy consumption, regulatory rulings, timing of maintenance on electric generating units, changes in mark-to-market valuations, changing commodity prices and other factors.
In preparing financial statements that conform to GAAP, management must make estimates and assumptions that affect the reported amounts of assets and liabilities, the reported amounts of revenues and expenses, and the disclosure of contingent assets and liabilities at the date of the financial statements. Actual results could differ from those estimates.
Certain prior year amounts have been reclassified to conform to the current year presentation.
UNBILLED REVENUE
Revenues on sales of electricity and natural gas are recognized when service is provided or the product is delivered. Unbilled revenues are recognized by applying customer billing rates to the estimated volumes of energy delivered but not yet billed. Unbilled revenues can vary significantly from period to period as a result of seasonality, weather, customer usage patterns, customer mix, average price in effect for customer classes, timing of rendering customer bills and meter reading schedules.
Unbilled revenues, which are included within Receivables and Receivables of variable interest entities (VIEs) on the Condensed Consolidated Balance Sheets, are presented in the following table.
(in millions)
June 30, 2016

 
December 31, 2015

Duke Energy
$
840

 
$
748

Duke Energy Carolinas
330

 
283

Progress Energy
209

 
172

Duke Energy Progress
104

 
102

Duke Energy Florida
105

 
70

Duke Energy Ohio
2

 
3

Duke Energy Indiana
38

 
31

Additionally, Duke Energy Ohio and Duke Energy Indiana sell nearly all of their retail accounts receivable to an affiliate, Cinergy Receivables Company, LLC (CRC), on a revolving basis. These transfers of receivables are accounted for as sales and include receivables for unbilled revenues. Accordingly, the receivables sold are not reflected on the Condensed Consolidated Balance Sheets of Duke Energy Ohio and Duke Energy Indiana. See Note 12 for further information. These receivables for unbilled revenues are shown in the table below.
(in millions)
June 30, 2016

 
December 31, 2015

Duke Energy Ohio
$
70

 
$
71

Duke Energy Indiana
109

 
97


36


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

AMOUNTS ATTRIBUTABLE TO CONTROLLING INTERESTS
Income (Loss) from Discontinued Operations, net of tax presented on the respective Condensed Consolidated Statements of Operations for Duke Energy and Progress Energy is attributable only to controlling interests for all periods presented. Other comprehensive income reported on the Condensed Consolidated Statements of Changes in Equity for Progress Energy is attributable only to controlling interests for all periods presented.
 
EXCISE TAXES
Certain excise taxes levied by state or local governments are required to be paid even if not collected from the customer. These taxes are recognized on a gross basis. Otherwise, excise taxes are accounted for net.
Excise taxes accounted for on a gross basis as both operating revenues and property and other taxes on the Condensed Consolidated Statements of Operations were as follows.
 
Three Months Ended June 30,
 
Six Months Ended June 30,
(in millions)
2016

 
2015

 
2016

 
2015

Duke Energy
$
87


$
97


$
178


$
197

Duke Energy Carolinas
7

 
9

 
15

 
18

Progress Energy
50

 
57

 
96

 
106

Duke Energy Progress
4

 
4

 
9

 
8

Duke Energy Florida
46

 
53

 
87

 
98

Duke Energy Ohio
22

 
23

 
51

 
55

Duke Energy Indiana
8

 
8

 
16

 
18

NEW ACCOUNTING STANDARDS
The new accounting standards adopted for 2016 and 2015 had no material impact on the presentation or results of operations, cash flows or financial position of the Duke Energy Registrants. The following accounting standard was adopted by the Duke Energy Registrants during 2015.
Balance Sheet Presentation of Debt Issuance Costs. In April and August of 2015, the Financial Accounting Standards Board (FASB) issued revised accounting guidance for the presentation of debt issuance costs. The core principle of this revised accounting guidance is that debt issuance costs are not assets, but adjustments to the carrying cost of debt. For Duke Energy, this revised accounting guidance was adopted retrospectively.
The implementation of this accounting standard resulted in a reduction of Other within Regulatory Assets and Deferred Debits and in Long-Term Debt of $192 million and $170 million on the Condensed Consolidated Balance Sheets as of June 30, 2016, and December 31, 2015, respectively.
The following new Accounting Standards Updates (ASUs) have been issued, but have not yet been adopted by Duke Energy, as of June 30, 2016.
Revenue from Contracts with Customers. In May 2014, the FASB issued revised accounting guidance for revenue recognition from contracts with customers. The core principle of this guidance is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. The amendments in this update also require disclosure of sufficient information to allow users to understand the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers.
For Duke Energy, the revised accounting guidance is effective for interim and annual periods beginning January 1, 2018. The guidance can be applied retrospectively to all prior reporting periods presented or retrospectively with a cumulative effect as of the initial date of application. Duke Energy is currently evaluating the requirements. The ultimate impact of the new standard has not yet been determined.
Leases. In February 2016, the FASB issued revised accounting guidance for leases. The core principle of this guidance is that a lessee should recognize the assets and liabilities that arise from leases on the balance sheet.
For Duke Energy, this guidance is effective for interim and annual periods beginning January 1, 2019, although it can be early adopted. The guidance is applied using a modified retrospective approach. Duke Energy is currently evaluating the requirements. Other than an expected increase in assets and liabilities, the ultimate impact of the new standard has not yet been determined.
Stock-Based Compensation and Income Taxes. In March 2016, the FASB issued revised accounting guidance for stock-based compensation and the associated income taxes. This standard changes certain aspects of accounting for stock-based payment awards to employees including the accounting for income taxes, statutory tax withholding requirements, as well as the classification on the Condensed Consolidated Statements of Cash Flows. This guidance will be applied prospectively, retrospectively, or using a modified retrospective transition method depending on the item changed.
For Duke Energy, this guidance is effective for interim and annual periods beginning January 1, 2017, although it can be early adopted. Duke Energy is currently evaluating the requirements. The primary change expected is an increase in the volatility of income tax expense.

37


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

2. ACQUISITIONS AND DISPOSITIONS
ACQUISITIONS
The Duke Energy Registrants consolidate assets and liabilities from acquisitions as of the purchase date, and include earnings from acquisitions in consolidated earnings after the purchase date.
Acquisition of Piedmont Natural Gas
On October 24, 2015, Duke Energy entered into an Agreement and Plan of Merger (Merger Agreement) with Piedmont Natural Gas Company, Inc. (Piedmont), a North Carolina corporation. Under the terms of the Merger Agreement, Duke Energy will acquire Piedmont for approximately $4.9 billion in cash and Piedmont will become a wholly owned subsidiary of Duke Energy. In addition, Duke Energy will assume Piedmont's existing debt, which was approximately $2.0 billion at April 30, 2016, the end of Piedmont's most recent filed quarter. The excess of the purchase price over the fair value of Piedmont's assets and liabilities on the acquisition date will be recorded as goodwill. Duke Energy estimates the transaction would result in incremental goodwill of approximately $3.5 billion. Duke Energy expects to finance the transaction with a combination of debt, equity issuances and other cash sources. As of June 30, 2016, Duke Energy had entered into $1.4 billion of forward-starting interest rate swaps to manage interest rate exposure for the expected financing of the Piedmont acquisition. For additional information on the forward-starting swaps, see Note 9.
In March 2016, Duke Energy marketed an equity offering of 10.6 million shares of common stock. In lieu of issuing equity at the time of the offering, Duke Energy entered into equity forward sale agreements (the Equity Forwards) with Barclays Capital, Inc. (Barclays). Duke Energy expects to settle the Equity Forwards on or around the closing date of the Piedmont acquisition. The net proceeds received upon settlement are expected to be used to finance a portion of the acquisition of Piedmont. For additional information regarding the Equity Forwards, see Note 13.
In connection with the Merger Agreement with Piedmont, Duke Energy entered into a $4.9 billion senior unsecured bridge financing facility (Bridge Facility) with Barclays. The Bridge Facility, if drawn upon, may be used to (i) fund the cash consideration for the transaction and (ii) pay certain fees and expenses in connection with the transaction. In November 2015, Barclays syndicated its commitment under the Bridge Facility to a broader group of lenders. Duke Energy does not expect to draw upon the Bridge Facility. The amount of the Bridge Facility is reduced by any financings related to the Piedmont acquisition entered into by Duke Energy, and has accordingly been reduced to approximately $3.2 billion as a result of the Equity Forwards and $1 billion of the commitments under a term loan amended and restated as of August 1, 2016. See Note 6, Term Loan Facility, for more information.
Piedmont's shareholders have approved the company's acquisition by Duke Energy and the Federal Trade Commission (FTC) has granted early termination of the 30-day waiting period under the federal Hart-Scott-Rodino Antitrust Improvements Act of 1976. On January 15, 2016, Duke Energy and Piedmont filed an application with the NCUC for approval of the proposed business combination and associated financing transactions. On January 29, 2016, the NCUC approved Duke Energy's proposed financing transactions. On March 7, 2016, the KPSC granted Duke Energy's declaratory request that the transaction does not constitute a change in control and does not require KPSC approval. The Tennessee Regulatory Authority approved Duke Energy's and Piedmont's request of the change in control resulting from the transaction at its March 14, 2016, meeting. On June 10, 2016 the North Carolina Public Staff reached an agreement with Duke Energy and Piedmont on certain stipulations and conditions for approval of the transaction. Duke Energy and Piedmont have also entered into settlement agreements with the Environmental Defense Fund (EDF) and the Carolina Utility Customers Association, Inc. (CUCA) resolving EDF's and CUCA's issues in the case.
On July 19, 2016, the NCUC concluded an evidentiary hearing for the proposed business combination. Proposed orders are due from all parties by August 25, 2016, after which the NCUC will rule on the application. Subject to receipt of NCUC approval and meeting closing conditions, Duke Energy and Piedmont expect to close the transaction by the end of 2016.
The Merger Agreement contains certain termination rights for both Duke Energy and Piedmont, and provides that, upon termination of the Merger Agreement under specified circumstances, Duke Energy would be required to pay a termination fee of $250 million to Piedmont and Piedmont would be required to pay Duke Energy a termination fee of $125 million.
See Note 4 for additional information regarding Duke Energy and Piedmont's joint investment in Atlantic Coast Pipeline, LLC (ACP).
Purchase of NCEMPA's Generation
On July 31, 2015, Duke Energy Progress completed the purchase of North Carolina Eastern Municipal Power Agency’s (NCEMPA) ownership interests in certain generating assets, fuel and spare parts inventory jointly owned with and operated by Duke Energy Progress for approximately $1.25 billion. This purchase was accounted for as an asset acquisition. The purchase resulted in the acquisition of a total of approximately 700 megawatts (MW) of generating capacity at Brunswick Nuclear Plant, Shearon Harris Nuclear Plant, Mayo Steam Plant and Roxboro Steam Plant. In connection with this transaction, Duke Energy Progress and NCEMPA entered into a 30-year wholesale power agreement, whereby Duke Energy Progress will sell power to NCEMPA to continue to meet the needs of NCEMPA customers.
The purchase price exceeded the historical carrying value of the acquired assets by $350 million, which was recognized as an acquisition adjustment and recorded in property, plant and equipment. Duke Energy Progress established a rider in North Carolina to recover the costs to acquire, operate and maintain interests in the assets purchased as allocated to its North Carolina retail operations, including the purchase acquisition adjustment, and included the purchase acquisition adjustment in wholesale power formula rates. Duke Energy Progress received an order from the PSCSC to defer the recovery of the South Carolina retail allocated costs of the asset purchased until the Duke Energy Progress' next general rate case, which was filed in July 2016. See Note 4, for additional information on the South Carolina Rate Case.

38


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

DISPOSITIONS
Potential Sale of International Energy
In February 2016, Duke Energy announced it had initiated a process to divest the International Energy business segment, excluding the equity method investment in National Methanol Company (NMC). Duke Energy is actively marketing the business. Non-binding offers have been received and are being evaluated. There is no assurance that this process will result in a transaction and the timing for execution of a potential transaction is uncertain. Proceeds from a successful sale would be used by Duke Energy to reduce debt and fund the operations and growth of domestic businesses. If the potential of a sale were to progress, it could result in classification of International Energy as assets held for sale and as a discontinued operation.
Based upon the advancement of the marketing efforts, Duke Energy performed recoverability tests of the long-lived asset groups of International Energy as of June 30, 2016. As a result, Duke Energy determined the carrying value of certain assets in Central America is not fully recoverable and recorded a pretax impairment charge of $194 million, which is included within Impairment Charges on the Condensed Consolidated Statements of Operations for the three and six months ended June 30, 2016. The impairment charge represents the excess of carrying value over the estimated fair value of the assets. The fair value of the assets was primarily determined from the income approach using discounted cash flows but also considered market information obtained in 2016.
As of June 30, 2016, the International Energy segment had a carrying value of approximately $2.4 billion, adjusted for approximately $589 million of cumulative foreign currency translation losses currently classified as accumulated other comprehensive loss.
Midwest Generation Exit
Duke Energy, through indirect subsidiaries, completed the sale of the Disposal Group to a subsidiary of Dynegy on April 2, 2015, for approximately $2.8 billion in cash. The nonregulated Midwest generation business included generation facilities with approximately 5,900 MW of owned capacity located in Ohio, Pennsylvania and Illinois. On April 1, 2015, prior to the sale, Duke Energy Ohio distributed its indirect ownership interest in the nonregulated Midwest generation business to a subsidiary of Duke Energy Corporation.
The Disposal Group's results of operations are classified as discontinued operations in the accompanying Condensed Consolidated Statements of Operations and Comprehensive Income. The following table presents the results of discontinued operations for the three and six months ended June 30, 2015.
 
Three Months Ended
 
Six Months Ended
 
June 30, 2015
 
June 30, 2015
 
 
 
Duke

 
 
 
Duke

 
Duke

 
Energy

 
Duke

 
Energy

(in millions)
Energy

 
Ohio

 
Energy

 
Ohio

Operating Revenues
$

 
$

 
$
543

 
$
412

Gain (Loss) on disposition
6

 

 
(37
)
 
(44
)
 
 
 
 
 
 
 
 
(Loss) Income before income taxes(a)
$
(80
)
 
$
(88
)
 
$
67

 
$
52

Income tax (benefit) expense
(21
)
 
(23
)
 
30

 
27

(Loss) Income from discontinued operations of the Disposal Group
(59
)
 
(65
)
 
37

 
25

Other, net of tax(b)
2

 

 
(3
)
 

(Loss) Income from Discontinued Operations, net of tax
$
(57
)
 
$
(65
)
 
$
34

 
$
25

(a)
The (Loss) Income before income taxes includes the pretax impact of a $71 million and $81 million charge for the agreement in principle reached in a lawsuit related to the Disposal Group for the three and six months ended June 30, 2015, respectively. Refer to Note 5 for further information related to the lawsuit.
(b)
Relates to discontinued operations of businesses not related to the Disposal Group and includes indemnifications provided for certain legal, tax and environmental matters, and foreign currency translation adjustments.
Commercial Portfolio utilized a revolving credit agreement (RCA) to support the operations of the nonregulated Midwest generation business. Interest expense associated with the RCA was allocated to discontinued operations. No other interest expense related to corporate level debt was allocated to discontinued operations. Duke Energy Ohio had a power purchase agreement with the Disposal Group for a portion of its standard service offer (SSO) supply requirement. The agreement and the SSO expired in May 2015.
3. BUSINESS SEGMENTS
Duke Energy evaluates segment performance based on segment income. Segment income is defined as income from continuing operations net of income attributable to noncontrolling interests. Segment income, as discussed below, includes intercompany revenues and expenses that are eliminated in the Condensed Consolidated Financial Statements. Certain governance costs are allocated to each segment. In addition, direct interest expense and income taxes are included in segment income.

39


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

Operating segments are determined based on information used by the chief operating decision-maker in deciding how to allocate resources and evaluate the performance of the business. During the first quarter of 2016, the Duke Energy chief operating decision-maker began to evaluate interim period segment performance based on financial information that includes the impact of income tax levelization within segment income. This represents a change from the previous measure, where the interim period impacts of income tax levelization were included within Other, and therefore excluded from segment income. As a result, prior period segment results presented have been recast to conform to this change.
Products and services are sold between affiliate companies and reportable segments of Duke Energy at cost. Segment assets as presented in the tables that follow exclude all intercompany assets.
DUKE ENERGY
Duke Energy has the following reportable operating segments: Regulated Utilities, International Energy and Commercial Portfolio.
Regulated Utilities conducts electric and natural gas operations that are substantially all regulated and, accordingly, qualify for regulatory accounting treatment. These operations are primarily conducted through the Subsidiary Registrants and are subject to the rules and regulations of the FERC, NRC, NCUC, PSCSC, FPSC, PUCO, IURC and KPSC.
International Energy operates and manages power generation facilities and engages in sales and marketing of electric power, natural gas and natural gas liquids outside the U.S. Its activities principally target power generation in Latin America. Additionally, International Energy owns a 25 percent interest in NMC, a large regional producer of methyl tertiary butyl ether (MTBE) located in Saudi Arabia. The investment in NMC is accounted for under the equity method of accounting. In February 2016, Duke Energy announced it had initiated a process to potentially divest its International Energy business segment, excluding the investment in NMC. See Note 2 for further information.
Commercial Portfolio builds, develops and operates wind and solar renewable generation and storage and energy transmission projects throughout the U.S. For periods subsequent to the sale of the Disposal Group, beginning in the second quarter of 2015, certain immaterial results of operations and related assets previously presented in the Commercial Portfolio segment are presented in Regulated Utilities and Other.
The remainder of Duke Energy’s operations is presented as Other, which is primarily comprised of unallocated corporate interest expense, unallocated corporate costs, contributions to the Duke Energy Foundation and the operations of Duke Energy’s wholly owned captive insurance subsidiary, Bison Insurance Company Limited (Bison).
 
Three Months Ended June 30, 2016
 
 
 
 
 
 
 
Total

 
 
 
 
 
 
 
Regulated

 
International

 
Commercial

 
Reportable

 
 
 
 
 
 
(in millions)
Utilities

 
Energy

 
Portfolio

 
Segments

 
Other

 
Eliminations

 
Consolidated

Unaffiliated revenues
$
5,090

 
$
270

 
$
112

 
$
5,472

 
$
12

 
$

 
$
5,484

Intersegment revenues
9

 

 

 
9

 
17

 
(26
)
 

Total revenues
$
5,099

 
$
270

 
$
112

 
$
5,481

 
$
29

 
$
(26
)
 
$
5,484

Segment income (loss)(a)(b)
$
718

 
$
(102
)
 
$
14

 
$
630

 
$
(120
)
 
$

 
$
510

Add back noncontrolling interests
 
 
 
 
 
 
 
 
 
 
 
 
3

Loss from discontinued operations, net of tax
 
 
 
 
 
 
 
 
 
 
 
 
(1
)
Net income
 
 
 
 
 
 
 
 
 
 
 
 
$
512

Segment assets
$
112,754

 
$
3,131

 
$
4,329

 
$
120,214

 
$
2,260

 
$
180

 
$
122,654

(a)
Other includes after-tax charges for costs to achieve mergers of $69 million, primarily due to unrealized losses on forward-starting interest rate swaps related to the Piedmont acquisition, and cost savings initiatives of $15 million primarily due to severance costs. See Notes 2 and 9 for additional information related to the forward-starting interest rate swaps.
(b)
International Energy includes an after-tax impairment charge of $145 million. See Note 2 for additional information.
 
Three Months Ended June 30, 2015
 
 
 
 
 
 
 
Total

 
 
 
 
 
 
 
Regulated

 
International

 
Commercial

 
Reportable

 
 
 
 
 
 
(in millions)
Utilities

 
Energy

 
Portfolio

 
Segments

 
Other

 
Eliminations

 
Consolidated

Unaffiliated revenues
$
5,211

 
$
287

 
$
75

 
$
5,573

 
$
16

 
$

 
$
5,589

Intersegment revenues
9

 

 

 
9

 
18

 
(27
)
 

Total revenues
$
5,220

 
$
287

 
$
75

 
$
5,582

 
$
34

 
$
(27
)
 
$
5,589

Segment income (loss)(a)(b)
$
632

 
$
52

 
$
(30
)
 
$
654

 
$
(51
)
 
$
(3
)
 
$
600

Add back noncontrolling interests
 
 
 
 
 
 
 
 
 
 
 
 
4

Loss from discontinued operations, net of tax(c)
 
 
 
 
 
 
 
 
 
 
 
 
(57
)
Net income
 
 
 
 
 
 
 
 
 
 
 
 
$
547

(a)    Other includes after-tax costs to achieve the Progress Energy merger of $14 million.

40


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

(b)
Commercial Portfolio includes state tax expense of $41 million, resulting from changes to state apportionment factors due to the sale of the Disposal Group, that does not qualify for discontinued operations. Refer to Note 2 for further information related to the sale.
(c)
Includes the after-tax impact of $46 million for the agreement in principle reached in a lawsuit related to the Disposal Group. Refer to Note 5 for further information related to the lawsuit.
 
Six Months Ended June 30, 2016
 
 
 
 
 
 
 
Total

 
 
 
 
 
 
 
Regulated

 
International

 
Commercial

 
Reportable

 
 
 
 
 
 
(in millions)
Utilities

 
Energy

 
Portfolio

 
Segments

 
Other

 
Eliminations

 
Consolidated

Unaffiliated revenues
$
10,340

 
$
516

 
$
227

 
$
11,083

 
$
23

 
$

 
$
11,106

Intersegment revenues
18

 

 

 
9

 
35

 
(53
)
 

Total revenues
$
10,358

 
$
516

 
$
227

 
$
11,092

 
$
58

 
$
(53
)
 
$
11,106

Segment income (loss)(a)(b)
$
1,413

 
$
21

 
$
41

 
$
1,475

 
$
(274
)
 
$

 
$
1,201

Add back noncontrolling interests
 
 
 
 
 
 
 
 
 
 
 
 
8

Income from discontinued operations, net of tax
 
 
 
 
 
 
 
 
 
 
 
 
2

Net income
 
 
 
 
 
 
 
 
 
 
 
 
$
1,211

(a)
Other includes after-tax charges for costs to achieve mergers of $143 million, primarily due to unrealized losses on forward-starting interest rate swaps related to the Piedmont acquisition, and cost savings initiatives of $27 million primarily due to severance costs. See Notes 2 and 9 for additional information related to the forward-starting interest rate swaps.
(b)
International Energy includes an after-tax impairment charge of $145 million. See Note 2 for additional information.
 
Six Months Ended June 30, 2015
 
 
 
 
 
 
 
Total

 
 
 
 
 
 
 
Regulated

 
International

 
Commercial

 
Reportable

 
 
 
 
 
 
(in millions)
Utilities

 
Energy

 
Portfolio

 
Segments

 
Other

 
Eliminations

 
Consolidated

Unaffiliated revenues
$
10,924

 
$
560

 
$
148

 
$
11,632

 
$
22

 
$

 
$
11,654

Intersegment revenues
19

 

 

 
19

 
39

 
(58
)
 

Total revenues
$
10,943

 
$
560

 
$
148

 
$
11,651

 
$
61

 
$
(58
)
 
$
11,654

Segment income (loss)(a)(b)
$
1,406

 
$
88

 
$
(23
)
 
$
1,471

 
$
(94
)
 
$
(4
)
 
$
1,373

Add back noncontrolling interests
 
 
 
 
 
 
 
 
 
 
 
 
7

Income from discontinued operations, net of tax(c)
 
 
 
 
 
 
 
 
 
 
 
 
34

Net income
 
 
 
 
 
 
 
 
 
 
 
 
$
1,414

(a)    Other includes after-tax costs to achieve the Progress Energy merger of $27 million.
(b)
Commercial Portfolio includes state tax expense of $41 million, resulting from changes to state apportionment factors due to the sale of the Disposal Group, that does not qualify for discontinued operations. Refer to Note 2 for further information related to the sale.
(c)
Includes after-tax impact of $53 million for the agreement in principle reached in a lawsuit related to the Disposal Group. Refer to Note 5 for further information related to the lawsuit.
SUBSIDIARY REGISTRANTS
The Subsidiary Registrants each have one reportable operating segment, Regulated Utilities, which generates, transmits, distributes and sells electricity, and for Duke Energy Ohio, also transports and sells natural gas. The remainder of operations is primarily comprised of unallocated corporate costs and classified as Other. The following table provides the amount of Other net expense.
 
Three Months Ended
Six Months Ended
 
June 30,
June 30,
(in millions)
2016

 
2015

2016

 
2015

Duke Energy Carolinas
$
(17
)
 
$
(10
)
$
(34
)
 
$
(18
)
Progress Energy(a)
(45
)
 
(42
)
(94
)
 
(84
)
Duke Energy Progress
(8
)
 
(4
)
(16
)
 
(8
)
Duke Energy Florida
(5
)
 
(3
)
(9
)
 
(6
)
Duke Energy Ohio
(10
)
 
(6
)
(19
)
 
(8
)
Duke Energy Indiana
(5
)
 
(2
)
(7
)
 
(4
)
(a)
Other for Progress Energy also includes interest expense on corporate debt instruments of $55 million and $111 million for the three and six months ended June 30, 2016, respectively, and $59 million and $119 million for the three and six months ended June 30, 2015, respectively.

41


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

The assets of the Subsidiary Registrants are substantially all included within the Regulated Utilities segment at June 30, 2016.
Duke Energy Ohio
Duke Energy Ohio had two reportable operating segments, Regulated Utilities and Commercial Portfolio, during 2015 prior to the sale of the nonregulated Midwest generation business. Duke Energy Ohio's Commercial Portfolio segment had total revenues of $14 million and segment loss of $9 million for the six months ended June 30, 2015. As a result of the sale discussed in Note 2, Commercial Portfolio no longer qualifies as a Duke Energy Ohio reportable operating segment. Therefore, beginning in the second quarter of 2015, all of the remaining assets and related results of operations previously presented in Commercial Portfolio are presented in Regulated Utilities and Other.
4. REGULATORY MATTERS
RATE RELATED INFORMATION
The NCUC, PSCSC, FPSC, IURC, PUCO and KPSC approve rates for retail electric and natural gas services within their states. The FERC approves rates for electric sales to wholesale customers served under cost-based rates (excluding Ohio, Kentucky and Indiana), as well as sales of transmission service.
Duke Energy Carolinas and Duke Energy Progress
Ash Basin Closure Costs Deferral
On July 13, 2016, in response to a joint petition of Duke Energy Carolinas and Duke Energy Progress the PSCSC issued an accounting order for the deferment into a regulatory account of certain costs incurred in connection with federal and state environmental remediation requirements related to the permanent closure of ash basins and other ash storage units at coal-fired generating facilities that have provided or are providing generation to customers located in South Carolina. The decision allows for ash basin closure expenses to be partially offset with excess regulatory liability amounts from the deferral of nuclear decommissioning costs that are collected from South Carolina retail customers and for Duke Energy Progress to offset incurred ash basin closure costs with costs of removal amounts collected from customers. The PSCSC's ruling does not change retail rates or the tariff amounts and in no way limits the PSCSC's ability to challenge the reasonableness of expenditures in subsequent proceedings.
FERC Transmission Return on Equity Complaints
On January 7, 2016, a group of transmission service customers filed a complaint with the FERC that the rate of return on equity of 10.2 percent in Duke Energy Carolinas' transmission formula rates is excessive and should be reduced to no higher than 8.49 percent, effective upon the complaint date. On the same date a similar complaint was filed with the FERC claiming that the rate of return on equity of 10.8 percent in Duke Energy Progress' transmission formula rates is excessive and should be reduced to no higher than 8.49 percent, effective upon the complaint date. On April 21, 2016, the FERC issued an order which consolidated the cases, set a refund effective date of January 7, 2016, and set the consolidated case for settlement and hearing. Duke Energy Carolinas and Duke Energy Progress do not expect the potential impact on results of operations, cash flows or financial position to be material.
Duke Energy Carolinas
Advanced Metering Infrastructure Deferral
On July 12, 2016, the PSCSC issued an accounting order for Duke Energy Carolinas to defer the financial effects of depreciation expense incurred for the installation of advanced metering infrastructure (AMI) meters, the carrying costs on the investment at its weighted average cost of capital and the carrying costs on the deferred costs at its weighted average cost of capital not to exceed $45 million. The decision also allows Duke Energy Carolinas to continue to depreciate the non-AMI meters to be replaced. Current retail rates will not change as a result of the decision and the PSCSC's ability to challenge the reasonableness of expenditures in subsequent proceedings is not limited.
William States Lee Combined Cycle Facility
On April 9, 2014, the PSCSC granted Duke Energy Carolinas and North Carolina Electric Membership Corporation (NCEMC) a Certificate of Environmental Compatibility and Public Convenience and Necessity (CECPCN) for the construction and operation of a 750 MW combined-cycle natural gas-fired generating plant at Duke Energy Carolinas' existing William States Lee Generating Station in Anderson, South Carolina. Duke Energy Carolinas began construction in July 2015 and estimates a cost to build of $600 million for its share of the facility, including allowance for funds used during construction (AFUDC). The project is expected to be commercially available in late 2017. NCEMC will own approximately 13 percent of the project. On July 3, 2014, the South Carolina Coastal Conservation League (SCCL) and Southern Alliance for Clean Energy (SACE) jointly filed a Notice of Appeal with the Court of Appeals of South Carolina (S.C. Court of Appeals) seeking the court's review of the PSCSC's decision, claiming the PSCSC did not properly consider a request related to a proposed solar facility prior to granting approval of the CECPCN. The S.C. Court of Appeals affirmed the PSCSC's decision on February 10, 2016, and on March 24, 2016, denied a request for rehearing filed by SCCL and SACE. On April 21, 2016, SCCL and SACE petitioned the South Carolina Supreme Court for review of the S.C. Court of Appeals decision. Duke Energy Carolinas filed its response on June 13, 2016, and SCCL and SACE filed a reply on June 23, 2016. Duke Energy Carolinas cannot predict the outcome of this matter.

42


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

Duke Energy Progress
South Carolina Rate Case
On July 1, 2016, Duke Energy Progress filed an application with the PSCSC requesting an average 14.5 percent increase in retail revenues. The requested rate change would increase annual revenues by approximately $79 million, with a rate of return on equity of 10.75 percent. The increase is designed to recover the cost of investment in new generation infrastructure, environmental expenditures including allocated historical ash basin closure costs and increased nuclear operating costs. Duke Energy Progress has requested new rates to be effective January 1, 2017. A hearing has been scheduled to begin on October 31, 2016. Duke Energy Progress cannot predict the outcome of this matter.
Western Carolinas Modernization Plan
On November 4, 2015, in response to community feedback, Duke Energy Progress announced a revised Western Carolinas Modernization Plan with an estimated cost of $1.1 billion. The revised plan includes retirement of the existing Asheville coal-fired plant, the construction of two 280 MW combined-cycle natural gas plants having dual fuel capability, with the option to build a third natural gas simple cycle unit in 2023 based upon the outcome of initiatives to reduce the region's power demand. The revised plan includes upgrades to existing transmission lines and substations, but eliminates the need for a new transmission line and a new substation associated with the project in South Carolina. The revised plan has the same overall project cost as the original plan and the plans to install solar generation remain unchanged. Duke Energy Progress has also proposed to add a pilot battery storage project. These investments will be made within the next seven years. Duke Energy Progress is also working with the local natural gas distribution company to upgrade an existing natural gas pipeline to serve the natural gas plant. The plan requires various approvals including regulatory approvals in North Carolina.
Duke Energy Progress filed for a Certificate of Public Convenience and Necessity (CPCN) with the NCUC for the new natural gas units on January 15, 2016. On March 28, 2016, the NCUC issued an order approving the CPCN for the new combined-cycle natural gas plants, but denying the CPCN for the contingent simple cycle unit without prejudice to Duke Energy Progress to refile for approval in the future. Construction of these plants is scheduled to begin in 2016 and the plants are expected to be in service by late 2019. Duke Energy Progress plans to file for future approvals related to the proposed solar generation and pilot battery storage project.
On May 27, 2016, NC WARN and The Climate Times filed a notice of appeal from the CPCN order to the N.C. Court of Appeals. On May 31, 2016, Duke Energy Progress filed a motion to dismiss the notice of appeal with the NCUC due to NC WARN's and The Climate Times' failure to post a required appeal bond. After a series of filings, an NCUC order, petitions to the N.C. Court of Appeals and an evidentiary hearing, on July 8, 2016, the NCUC issued an order setting NC WARN's and The Climate Times' appeal bond at $98 million. On July 28, 2016, NC WARN and The Climate Times filed a notice of appeal and exceptions from the NCUC's July 8, 2016, appeal bond order. On August 2, 2016, the NCUC granted Duke Energy Progress' motion to dismiss NC WARN's and The Climate Times' notice of appeal from the CPCN order due to failure to post the requisite bond. Duke Energy Progress cannot predict the outcome of this matter.
The carrying value of the 376 MW Asheville coal-fired plant, including associated ash basin closure costs, of $506 million and $548 million are included in Generation facilities to be retired, net on Duke Energy Progress' Condensed Consolidated Balance Sheet as of June 30, 2016 and December 31, 2015, respectively.
Duke Energy Florida
Hines Chiller Uprate Project
On May 20, 2016, Duke Energy Florida filed a petition seeking approval to include in base rates the revenue requirement for a Chiller Uprate Project (Uprate Project) at the Hines station. Duke Energy Florida proposes to complete the Uprate Project in two phases: phase one work on Hines Units 1-3 and the common equipment to be completed and placed into service in October 2016; and phase two work on Hines Unit 4 to be completed and placed into service in January 2017. The final construction cost estimate for both phases of approximately $150 million is below the cost estimate provided during the need determination proceeding. Duke Energy Florida estimates the annual retail revenue requirements for phases one and two to be approximately $16 million and $3 million, respectively. Duke Energy Florida’s petition seeks approval of both revenue requirements, but only seeks to include the phase one revenue requirement in base rates and customer bills beginning November 2016, and will separately petition to include the phase two revenue requirement in base rates and customer bills beginning February 2017. Duke Energy Florida cannot predict the outcome of this matter.
Purchase of Osprey Energy Center
In December 2014, Duke Energy Florida and Osprey Energy Center, LLC, a wholly owned subsidiary of Calpine Corporation (Calpine), entered into an Asset Purchase and Sale Agreement for the purchase of a 599 MW combined-cycle natural gas plant in Auburndale, Florida (Osprey Plant acquisition) for approximately $166 million. In July 2015, the FERC and the FPSC issued separate orders of approval for the Osprey Plant acquisition. The Hart-Scott-Rodino waiting period expired on May 2, 2016. Closing of the acquisition is expected to occur by the first quarter of 2017, upon the expiration of an existing Power Purchase Agreement between Calpine and Duke Energy Florida. In anticipation of closing, in August 2016, Duke Energy Florida filed a petition seeking approval to include in base rates the revenue requirements for the Osprey Plant acquisition to be included in customer bills beginning in February 2017. Duke Energy Florida estimates the retail revenue requirements to be approximately $48 million.

43


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

Crystal River Unit 3 Regulatory Asset
In June 2015, the governor of Florida signed legislation to allow utilities to issue nuclear asset-recovery bonds to finance the recovery of certain retired nuclear generation assets, with approval of the FPSC. In November 2015, the FPSC issued a financing order approving Duke Energy Florida’s request to issue nuclear asset-recovery bonds to finance its unrecovered regulatory asset related to Crystal River Unit 3 (Crystal River 3) through a wholly owned special purpose entity. Nuclear asset-recovery bonds replace the base rate recovery methodology authorized by the 2013 Revised and Restated Stipulation and Settlement Agreement (2013 Agreement) and result in a lower rate impact to customers with a recovery period of approximately 20 years.
Pursuant to provisions in Florida Statutes and the FPSC financing order, in 2016, Duke Energy Florida formed Duke Energy Florida Project Finance, LLC (DEFPF), a wholly owned, bankruptcy remote special purpose subsidiary for the purpose of issuing nuclear asset-recovery bonds. In June 2016, DEFPF issued $1,294 million aggregate principal amount of senior secured bonds (nuclear asset-recovery bonds) to finance the recovery of Duke Energy Florida's Crystal River 3 regulatory asset.
In connection with this financing, net proceeds to DEFPF of approximately $1,287 million, after underwriting costs, were used to acquire nuclear asset-recovery property from Duke Energy Florida and to pay transaction related expenses. The nuclear asset-recovery property includes the right to impose, bill, collect and adjust a non-bypassable nuclear asset-recovery charge, to be collected on a per kilowatt-hour basis from all Duke Energy Florida retail customers until the bonds are paid in full. Duke Energy Florida began collecting the nuclear asset-recovery charge on behalf of DEFPF in customer rates in July 2016.
See Notes 6 and 12 for additional information.
Duke Energy Ohio
Natural Gas Pipeline Extension
Duke Energy Ohio is proposing to install a new natural gas pipeline in its Ohio service territory to increase system reliability and enable the retirement of older infrastructure. The proposed project involves the installation of a natural gas line and is estimated to cost between $100 million and $150 million. Duke Energy Ohio is currently evaluating potential routes and has conducted public informational meetings. Duke Energy Ohio will narrow the route options to two and then make a filing with the Ohio Power Siting Board for approval of one of the two proposed routes.
Advanced Metering Infrastructure
On April 25, 2016, Duke Energy Kentucky filed with the KPSC an application for approval of a certificate of public convenience and necessity for the construction of advanced metering infrastructure. Duke Energy Kentucky anticipates that the estimated $49 million project, if approved, will take about two years to complete. Duke Energy Kentucky also requested approval to establish a regulatory asset of approximately $10 million for the remaining book value of existing meter equipment and inventory that will be replaced. On July 20, 2016, the Kentucky Attorney General, the only intervenor in the proceeding, moved to dismiss the application. Duke Energy Kentucky filed its opposition to the Kentucky Attorney General's motion to dismiss on July 27, 2016. Duke Energy Kentucky cannot predict the outcome of this matter.
Accelerated Natural Gas Service Line Replacement Rider
On January 20, 2015, Duke Energy Ohio filed an application for approval of an accelerated natural gas service line replacement program (ASRP). Under the ASRP, Duke Energy Ohio proposes to replace certain natural gas service lines on an accelerated basis. The program is proposed to last 10 years. Through the ASRP, Duke Energy Ohio also proposes to complete preliminary survey and investigation work related to natural gas service lines that are customer owned and for which it does not have valid records and, further, to relocate interior natural gas meters to suitable exterior locations where such relocation can be accomplished. Duke Energy Ohio projects total capital and operations and maintenance expenditures under the ASRP to approximate $320 million. The filing also seeks approval of Rider ASRP to recover related expenditures. Duke Energy Ohio proposes to update Rider ASRP on an annual basis. Duke Energy Ohio’s application is pending before the PUCO and it is uncertain when an order will be issued. Intervenors oppose the ASRP, primarily because they believe the program is neither required nor necessary under federal pipeline regulation. The hearing concluded on November 19, 2015, and initial and reply briefs were filed, with briefing complete on December 23, 2015. Duke Energy Ohio cannot predict the outcome of this matter.
Energy Efficiency Cost Recovery
On March 28, 2014, Duke Energy Ohio filed an application for recovery of program costs, lost distribution revenue and performance incentives related to its energy efficiency and peak demand reduction programs. These programs are undertaken to comply with environmental mandates set forth in Ohio law. After a comment period, the PUCO approved Duke Energy Ohio’s application, but found that Duke Energy Ohio was not permitted to use banked energy savings from previous years in order to calculate the amount of allowed incentive. This conclusion represented a change to the cost recovery mechanism that had been agreed to by intervenors and approved by the PUCO in previous cases. The PUCO granted the applications for rehearing filed by Duke Energy Ohio and an intervenor on July 8, 2015. Substantive ruling on the application for rehearing is pending. On January 6, 2016, Duke Energy Ohio and PUCO Staff entered into a stipulation pending PUCO approval, resolving the issues related to, among other things, performance incentives and the PUCO Staff audit of 2013 costs. Based on the stipulation, in December 2015, Duke Energy Ohio re-established approximately $20 million of revenues that had been reversed in the second quarter of 2015. A hearing on the stipulation commenced on March 10, 2016, and the post-hearing briefing has concluded. Duke Energy Ohio cannot predict the outcome of this matter.

44


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

2012 Natural Gas Rate Case/Manufactured Gas Plant Cost Recovery
On November 13, 2013, the PUCO issued an order approving a settlement of Duke Energy Ohio’s natural gas base rate case and authorizing the recovery of costs incurred between 2008 and 2012 for environmental investigation and remediation of two former manufactured gas plant (MGP) sites. The order contained deadlines for the recovery of such costs. Specifically, for the property known as the East End site, PUCO established a deadline of December 31, 2016, and for the West End site, a deadline of December 31, 2019. The PUCO authorized Duke Energy Ohio to seek to extend these deadlines due to certain circumstances. On May 16, 2016, Duke Energy Ohio filed an application to extend the deadline for cost recovery applicable to the East End site. The order also authorized Duke Energy Ohio to continue deferring environmental investigation and remediation costs incurred subsequent to 2012 and to submit annual filings to adjust the MGP rider for future costs. Duke Energy Ohio submitted MGP rider update filings in 2014, 2015, and 2016 for recovery of costs incurred in 2013, 2014, and 2015, which are pending approval. Duke Energy Ohio cannot predict the outcome of this matter.
Regional Transmission Organization Realignment
Duke Energy Ohio, including Duke Energy Kentucky, transferred control of its transmission assets from Midcontinent Independent System Operator, Inc. (MISO) to PJM Interconnection, LLC (PJM), effective December 31, 2011. The PUCO approved a settlement related to Duke Energy Ohio’s recovery of certain costs of the Regional Transmission Organization (RTO) realignment via a non-bypassable rider. Duke Energy Ohio is allowed to recover all MISO Transmission Expansion Planning (MTEP) costs, including but not limited to Multi Value Project (MVP) costs, directly or indirectly charged to Ohio customers. Duke Energy Ohio also agreed to vigorously defend against any charges for MVP projects from MISO. The KPSC also approved a request to effect the RTO realignment, subject to a commitment not to seek double recovery in a future rate case of the transmission expansion fees that may be charged by MISO and PJM in the same period or overlapping periods.
Duke Energy Ohio had a recorded liability for its exit obligation and share of MTEP costs, excluding MVP, of $91 million and $92 million, respectively, at June 30, 2016 and December 31, 2015, within Other in Current liabilities and Other in Deferred credits and other liabilities on Duke Energy Ohio’s Condensed Consolidated Balance Sheets. The retail portion of MTEP costs billed by MISO are recovered by Duke Energy Ohio through a non-bypassable rider. As of June 30, 2016 and December 31, 2015, Duke Energy Ohio had $72 million recorded in Regulatory assets on the Condensed Consolidated Balance Sheets.
MVP. MISO approved 17 MVP proposals prior to Duke Energy Ohio’s exit from MISO on December 31, 2011. Construction of these projects is expected to continue through 2020. Costs of these projects, including operating and maintenance costs, property and income taxes, depreciation and an allowed return, are allocated and billed to MISO transmission owners.
On December 29, 2011, MISO filed a tariff with the FERC providing for the allocation of MVP costs to a withdrawing owner based on monthly energy usage. The FERC set for hearing (i) whether MISO’s proposed cost allocation methodology to transmission owners who withdrew from MISO prior to January 1, 2012, is consistent with the tariff at the time of their withdrawal from MISO and, (ii) if not, what the amount of and methodology for calculating any MVP cost responsibility should be. In 2012, MISO estimated Duke Energy Ohio’s MVP obligation over the period from 2012 to 2071 at $2.7 billion, on an undiscounted basis. On July 16, 2013, a FERC Administrative Law Judge (ALJ) issued an initial decision. Under this initial decision, Duke Energy Ohio would be liable for MVP costs. Duke Energy Ohio filed exceptions to the initial decision, requesting FERC to overturn the ALJ’s decision.
On October 29, 2015, the FERC issued an order reversing the ALJ's decision. The FERC ruled the cost allocation methodology is not consistent with the MISO tariff and that Duke Energy Ohio has no liability for MVP costs after its withdrawal from MISO. On May 19, 2016, the FERC denied the request for rehearing filed by MISO and the MISO Transmission Owners. On July 15, 2016, the MISO Transmission Owners filed a petition for review with the U.S. Court of Appeals for the Sixth Circuit. Duke Energy Ohio cannot predict the outcome of this matter.
Duke Energy Indiana
Coal Combustion Residual Plan
On March 17, 2016, Duke Energy Indiana filed with the IURC a request for approval of its first group of federally mandated Coal Combustion Residual (CCR) rule compliance projects (Phase I CCR Compliance Projects) to comply with the U.S. Environmental Protection Agency's (EPA) CCR rule. The projects in this Phase I filing are CCR compliance projects, including the conversion of Cayuga and Gibson Stations to dry bottom ash handling and related water treatment. Duke Energy Indiana has requested timely recovery of approximately $380 million in retail capital costs and incremental operating and maintenance costs under a federal mandate tracker which provides for timely recovery of 80 percent of such costs and deferral with carrying costs of 20 percent of such costs for recovery in a subsequent retail base rate case. An evidentiary hearing is scheduled for November 2016. Duke Energy Indiana cannot predict the outcome of this matter.
Edwardsport Integrated Gasification Combined Cycle Plant
On November 20, 2007, the IURC granted Duke Energy Indiana a CPCN for the construction of the Edwardsport Integrated Gasification Combined Cycle (IGCC) Plant. The Citizens Action Coalition of Indiana, Inc., Sierra Club, Inc., Save the Valley, Inc., and Valley Watch, Inc. (collectively, the Joint Intervenors) were intervenors in several matters related to the Edwardsport IGCC Plant. The Edwardsport IGCC Plant was placed in commercial operation in June 2013. Costs for the Edwardsport IGCC Plant are recovered from retail electric customers via a tracking mechanism, the IGCC rider.
The ninth semi-annual IGCC rider order was appealed by the Joint Intervenors. The proceeding has been remanded to the IURC for further proceedings and additional findings on the tax in-service issue. An evidentiary hearing has been set for September 13, 2016.

45


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

The 11th through 15th semi-annual IGCC riders and a subdocket to Duke Energy Indiana's fuel adjustment clause remain pending at the IURC. Issues in these filings include the determination whether the IGCC plant was properly declared in-service for ratemaking purposes in June 2013 and a review of the operational performance of the plant. On September 17, 2015, Duke Energy Indiana, the Office of Utility Consumer Counselor, the Industrial Group and Nucor Steel Indiana reached a settlement agreement to resolve these pending issues. On January 15, 2016, The Citizens Action Coalition of Indiana, Inc., Sierra Club, Save the Valley and Valley Watch joined a revised settlement (IGCC settlement). The IGCC settlement will result in customers not being billed for previously incurred operating costs of $87.5 million, and for additional Duke Energy Indiana payments and commitments of $5.5 million for attorneys’ fees and amounts to fund consumer programs. Attorneys’ fees and expenses for the new settling parties will be addressed in a separate proceeding. Duke Energy Indiana recognized pretax impairment and related charges of $93 million in 2015. Additionally, under the IGCC settlement, the operating and maintenance expenses and ongoing maintenance capital at the plant are subject to certain caps during the years of 2016 and 2017. The IGCC settlement also includes a commitment to either retire or stop burning coal by December 31, 2022, at the Gallagher Station. Pursuant to the IGCC settlement, the in-service date used for accounting and ratemaking will remain as June 2013. Remaining deferred costs will be recovered over eight years and not earn a carrying cost. The IGCC settlement, which is opposed by an intervenor, is subject to IURC approval. An evidentiary hearing on the IGCC settlement was held on April 18, 2016, and a decision is expected in the third quarter of 2016. As of June 30, 2016, deferred costs related to the project are approximately $175 million. Under the IGCC settlement, future IGCC riders will be filed annually, rather than every six months, with the next filing scheduled for first quarter 2017.
Duke Energy Indiana cannot predict the outcome of these matters or future IGCC rider proceedings.
FERC Transmission Return on Equity Complaint
Customer groups have filed with the FERC complaints against MISO and its transmission-owning members, including Duke Energy Indiana, alleging, among other things, that the current base rate of return on equity earned by MISO transmission owners of 12.38 percent is unjust and unreasonable. The latest complaint, filed on February 12, 2015, claims the base rate of return on equity should be reduced to 8.67 percent and requests a consolidation of complaints. The motion to consolidate complaints was denied. On January 5, 2015, the FERC issued an order accepting the MISO transmission owners 0.50 percent adder to the base rate of return on equity based on participation in an RTO subject to it being applied to a return on equity that is shown to be just and reasonable in the pending return on equity complaints. A hearing in the base return on equity proceeding was held in August 2015. On December 22, 2015, the presiding FERC ALJ in the first complaint issued an Initial Decision in which he set the base rate of return on equity at 10.32 percent. On June 30, 2016, the presiding FERC ALJ in the second complaint issued an Initial Decision setting the base rate of return on equity at 9.70 percent. The Initial Decisions will be reviewed by the FERC. Duke Energy Indiana currently believes these matters will have an immaterial impact on its results of operations, cash flows and financial position.
Grid Infrastructure Improvement Plan
On August 29, 2014, pursuant to a new statute, Duke Energy Indiana filed a seven-year grid infrastructure improvement plan with the IURC with an estimated cost of $1.9 billion, focusing on the reliability, integrity and modernization of the transmission and distribution system. The plan also provided for cost recovery through a transmission and distribution rider (T&D Rider). In May 2015, the IURC denied the original proposal due to an insufficient level of detailed projects and cost estimates in the plan. On December 7, 2015, Duke Energy Indiana filed a revised infrastructure improvement plan with an estimated cost of $1.8 billion in response to guidance from IURC orders and the Indiana Court of Appeals decisions related to this new statute. The revised plan uses a combination of advanced technology and infrastructure upgrades to improve service to customers and provide them with better information about their energy use. It also provides for cost recovery through a T&D rider. In March 2016, Duke Energy Indiana entered into a settlement with all parties to the proceeding except the Citizens Action Coalition of Indiana, Inc. The settlement agreement decreased the capital expenditures eligible for timely recovery of costs in the seven-year plan to approximately $1.4 billion, including the removal of an AMI project. The settlement provided for deferral accounting for depreciation and post-in-service carrying costs for AMI projects outside the seven-year plan. Duke Energy Indiana withdrew its request for a regulatory asset for current meters and will retain any savings associated with future AMI installation until the next retail base rate case, which is required to be filed prior to the end of the seven-year plan. Under the settlement, the return on equity to be used in the T&D Rider is 10 percent. The IURC approved the settlement and issued a final order on June 29, 2016.
OTHER REGULATORY MATTERS
Atlantic Coast Pipeline
On September 2, 2014, Duke Energy, Dominion Resources (Dominion), Piedmont and AGL Resources announced the formation of a company, ACP, to build and own the proposed Atlantic Coast Pipeline (the pipeline), a 564-mile interstate natural gas pipeline. The pipeline is designed to meet the needs identified in requests for proposals by Duke Energy Carolinas, Duke Energy Progress and Piedmont. Dominion will build and operate the pipeline and has a 45 percent ownership percentage in ACP. Duke Energy has a 40 percent ownership interest in ACP through its Commercial Portfolio segment. Piedmont owns 10 percent and the remaining share is owned by AGL Resources. Duke Energy Carolinas and Duke Energy Progress, among others, will be customers of the pipeline. Purchases will be made under several 20-year supply contracts, subject to state regulatory approval. In October 2014, the NCUC and PSCSC approved the Duke Energy Carolinas and Duke Energy Progress requests to enter into certain affiliate agreements, pay compensation to ACP and to grant a waiver of certain Code of Conduct provisions relating to contractual and jurisdictional matters. On September 18, 2015, ACP filed an application with the FERC requesting a CPCN authorizing ACP to construct the pipeline. FERC approval of the application is expected in early 2017 and construction is projected to begin in summer of 2017, with a targeted in-service date of late 2018. ACP is working with various agencies to develop the final pipeline route. ACP also requested approval of an open access tariff and the precedent agreements it entered into with future pipeline customers, including Duke Energy Carolinas and Duke Energy Progress.
On October 24, 2015, Duke Energy entered into a Merger Agreement with Piedmont. The ACP partnership agreement includes provisions to allow Dominion an option to purchase additional ownership interest in ACP to maintain a leading ownership percentage. Any change in ownership interests is not expected to be material to Duke Energy. Refer to Note 2 for further information related to Duke Energy's proposed acquisition of Piedmont.

46


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

Sabal Trail Transmission, LLC Pipeline
On May 4, 2015, Duke Energy acquired a 7.5 percent ownership interest from Spectra Energy in the proposed 500-mile Sabal Trail natural gas pipeline. Spectra Energy will continue to own 59.5 percent of the Sabal Trail pipeline and NextEra Energy will own the remaining 33 percent. The Sabal Trail pipeline will traverse Alabama, Georgia and Florida to meet rapidly growing demand for natural gas in those states. The primary customers of the Sabal Trail pipeline, Duke Energy Florida and Florida Power & Light Company (FP&L), have each contracted to buy pipeline capacity for 25-year initial terms. On February 3, 2016, the FERC issued an order granting the request for a CPCN to construct and operate the Sabal Trail pipeline. The Sabal Trail pipeline requires additional regulatory approvals and is scheduled to begin service in mid-2017.
Progress Energy Merger FERC Mitigation
In June 2012, the FERC approved the merger with Progress Energy, including Duke Energy and Progress Energy’s revised market power mitigation plan, the Joint Dispatch Agreement (JDA) and the joint Open Access Transmission Tariff. The revised market power mitigation plan provided for the acceleration of one transmission project and the completion of seven other transmission projects (Long-Term FERC Mitigation) and interim firm power sale agreements during the completion of the transmission projects (Interim FERC Mitigation). The Long-Term FERC Mitigation was expected to increase power imported into the Duke Energy Carolinas and Duke Energy Progress service areas and enhance competitive power supply options in the service areas. All of these projects were completed in or before 2014.
Following the closing of the merger, outside counsel reviewed Duke Energy’s mitigation plan and discovered a technical error in the calculations. On December 6, 2013, Duke Energy submitted a filing to the FERC disclosing the error and arguing that no additional mitigation is necessary. The city of New Bern filed a protest and requested that FERC order additional mitigation. On October 29, 2014, the FERC ordered that the amount of the stub mitigation be increased from 25 MW to 129 MW. The stub mitigation is Duke Energy’s commitment to set aside for third parties a certain quantity of firm transmission capacity from Duke Energy Carolinas to Duke Energy Progress during summer off-peak hours. The FERC also ordered that Duke Energy operate certain phase shifters to create additional import capability and that such operation be monitored by an independent monitor. The costs to comply with this order are not material. The FERC also referred Duke Energy’s failure to expressly designate the phase shifter reactivation as a mitigation project in the original mitigation plan filing in March 2012 to the FERC Office of Enforcement for further inquiry. In response, and since December 2014, the FERC Office of Enforcement has conducted a nonpublic investigation of Duke Energy's market power analyses included in the Progress merger filings submitted to FERC. Duke Energy cannot predict the outcome of this investigation.
Potential Coal Plant Retirements
The Subsidiary Registrants periodically file Integrated Resource Plans (IRP) with their state regulatory commissions. The IRPs provide a view of forecasted energy needs over a long term (10 to 20 years), and options being considered to meet those needs. Recent IRPs filed by the Subsidiary Registrants included planning assumptions to potentially retire certain coal-fired generating facilities in Florida and Indiana earlier than their current estimated useful lives. These facilities do not have the requisite emission control equipment, primarily to meet EPA regulations recently approved or proposed.
The table below contains the net carrying value of generating facilities planned for retirement or included in recent IRPs as evaluated for potential retirement due to a lack of requisite environmental control equipment. Dollar amounts in the table below are included in Net property, plant and equipment on the Condensed Consolidated Balance Sheets as of June 30, 2016.
 
 
 
Remaining Net

 
Capacity

 
Book Value(a)

 
(in MW)

 
(in millions)

Progress Energy and Duke Energy Florida
 
 
 
Crystal River Units 1 and 2
873

 
126

Duke Energy Indiana
 
 
 
Wabash River Unit 6(b)
318

 
34

Gallagher Units 2 and 4(c)
280

 
135

Total Duke Energy
1,471

 
295

(a)
Remaining net book value amounts exclude any capitalized asset retirement costs.
(b)
In April 2016, Wabash River 6 terminated coal burning operations and is targeted for retirement by the end of 2016. The total net book value of $93 million for the retail portion of Wabash River Unit 6 and the retail portion of capitalized asset retirement costs for Wabash River Units 2 through 6 is classified as Generation facilities to be retired, net on Duke Energy Indiana's Condensed Consolidated Balance Sheet at June 30, 2016.
(c)
Duke Energy Indiana committed to either retire or stop burning coal at Gallagher Units 2 and 4 by December 31, 2022, as part of the proposed settlement of Edwardsport IGCC matters.

47


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

On October 23, 2015, the EPA published in the Federal Register the Clean Power Plan (CPP) rule for regulating carbon dioxide (CO2) emissions from existing fossil fuel-fired electric generating units (EGUs). The CPP establishes CO2 emission rates and mass cap goals that apply to fossil fuel-fired generation. Under the CPP, states are required to develop and submit a final compliance plan, or an initial plan with an extension request, to the EPA by September 6, 2016, or no later than September 6, 2018, with an approved extension. These state plans are subject to EPA approval, with a federal plan applied to states that fail to submit a plan to the EPA or if a state plan is not approved. Legal challenges to the CPP have been filed by stakeholders and motions to stay the requirements of the rule pending the outcome of the litigation were granted by the U.S. Supreme Court in February 2016. Final resolution of these legal challenges could take several years. Compliance with CPP could cause the industry to replace coal generation with natural gas and renewables, especially in states that have significant CO2 reduction targets under the rule. Costs to operate coal-fired generation plants continue to grow due to increasing environmental compliance requirements, including ash management costs unrelated to CPP, and this may result in the retirement of coal-fired generation plants earlier than the current end of useful lives. Duke Energy continues to evaluate the need to retire generating facilities and plans to seek regulatory recovery, where appropriate, for amounts that have not been recovered upon asset retirements. However, recovery is subject to future regulatory approval, including the recovery of carrying costs on remaining book values, and therefore cannot be assured.
Refer to the "Western Carolinas Modernization Plan" discussion above for details of Duke Energy Progress' planned retirements.
5. COMMITMENTS AND CONTINGENCIES
ENVIRONMENTAL
Duke Energy is subject to international, federal, state and local regulations regarding air and water quality, hazardous and solid waste disposal and other environmental matters. The Subsidiary Registrants are subject to federal, state and local regulations regarding air and water quality, hazardous and solid waste disposal and other environmental matters. These regulations can be changed from time to time, imposing new obligations on the Duke Energy Registrants.
Remediation Activities
In addition to Asset Retirement Obligations recorded as a result of various environmental regulations, the Duke Energy Registrants are responsible for environmental remediation at various sites. These include certain properties that are part of ongoing operations and sites formerly owned or used by Duke Energy entities. These sites are in various stages of investigation, remediation and monitoring. Managed in conjunction with relevant federal, state and local agencies, remediation activities vary based upon site conditions and location, remediation requirements, complexity and sharing of responsibility. If remediation activities involve joint and several liability provisions, strict liability or cost recovery or contribution actions, the Duke Energy Registrants could potentially be held responsible for environmental impacts caused by other potentially responsible parties, and may also benefit from insurance policies or contractual indemnities that cover some or all cleanup costs. Liabilities are recorded when losses become probable and are reasonably estimable. The total costs that may be incurred cannot be estimated because the extent of environmental impact, allocation among potentially responsible parties, remediation alternatives and/or regulatory decisions have not yet been determined. Additional costs associated with remediation activities are likely to be incurred in the future and could be significant. Costs are typically expensed as Operation, maintenance and other in the Condensed Consolidated Statements of Operations unless regulatory recovery of the costs is deemed probable.
The following tables contain information regarding reserves for probable and estimable costs related to the various environmental sites. These reserves are recorded in Other within Deferred Credits and Other Liabilities on the Condensed Consolidated Balance Sheets.
 
Six Months Ended June 30, 2016
 
 
 
Duke

 
 
 
Duke

 
Duke

 
Duke

 
Duke

 
Duke

 
Energy

 
Progress

 
Energy

 
Energy

 
Energy

 
Energy

(in millions)
Energy

 
Carolinas

 
Energy

 
Progress

 
Florida

 
Ohio

 
Indiana

Balance at beginning of period
$
97

 
$
10

 
$
17

 
$
3

 
$
14

 
$
54

 
$
12

Provisions/adjustments
28

 
3

 
4

 
1

 
3

 
1

 
21

Cash reductions
(7
)
 
(2
)
 
(4
)
 
(1
)
 
(3
)
 
(1
)
 
(1
)
Balance at end of period
$
118

 
$
11

 
$
17

 
$
3

 
$
14

 
$
54

 
$
32

 
Six Months Ended June 30, 2015
 
 
 
Duke

 
 
 
Duke

 
Duke

 
Duke

 
Duke

 
Duke

 
Energy

 
Progress

 
Energy

 
Energy

 
Energy

 
Energy

(in millions)
Energy

 
Carolinas

 
Energy

 
Progress

 
Florida

 
Ohio

 
Indiana

Balance at beginning of period
$
97

 
$
10

 
$
17

 
$
5

 
$
12

 
$
54

 
$
10

Provisions/adjustments
5

 

 
2

 

 
2

 
1

 
3

Cash reductions
(4
)
 

 
(2
)
 
(1
)
 
(1
)
 
(1
)
 
(1
)
Balance at end of period
$
98

 
$
10

 
$
17

 
$
4

 
$
13

 
$
54

 
$
12


48


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

Additional losses in excess of recorded reserves that could be incurred for the stages of investigation, remediation and monitoring for environmental sites that have been evaluated at this time are not material except as presented in the table below.
(in millions)
 
Duke Energy
$
75

Duke Energy Carolinas
22

Duke Energy Ohio
42

Duke Energy Indiana
7

North Carolina and South Carolina Ash Basins
On February 2, 2014, a break in a stormwater pipe beneath an ash basin at Duke Energy Carolinas’ retired Dan River Steam Station caused a release of ash basin water and ash into the Dan River. On February 8, 2014, a permanent plug was installed in the stormwater pipe, stopping the release of materials into the river. Duke Energy Carolinas estimates 30,000 to 39,000 tons of ash and 24 million to 27 million gallons of basin water were released into the river. In July 2014, Duke Energy completed remediation work identified by the EPA and continues to cooperate with the EPA's civil enforcement process. Future costs related to the Dan River release, including pending or future state or federal civil enforcement proceedings, future regulatory directives, natural resources damages, additional pending litigation, future claims or litigation and long-term environmental impact costs, cannot be reasonably estimated at this time.
North Carolina Department of Environmental Quality (NCDEQ), formerly the North Carolina Department of Environment and Natural Resources, has historically assessed Duke Energy Carolinas and Duke Energy Progress with Notice of Violations (NOV) for violations that were most often resolved through satisfactory corrective actions and minor, if any, fines or penalties. Subsequent to the Dan River matter discussed above, Duke Energy Carolinas and Duke Energy Progress have been served with a higher level of Notices of Violation (NOVs), including for violations at L.V. Sutton Plant and Dan River Steam Station. In August 2014, NCDEQ issued an NOV for alleged groundwater violations at Duke Energy Progress' L.V. Sutton Plant. On March 10, 2015, NCDEQ issued a civil penalty of approximately $25 million to Duke Energy Progress for environmental damages related to groundwater contamination at the L.V. Sutton Plant. On February 8, 2016, NCDEQ assessed a penalty of approximately $6.8 million, including enforcement costs, against Duke Energy Carolinas related to stormwater pipes and associated discharges at the Dan River Steam Station. Duke Energy Carolinas recorded a charge in December 2015 for this penalty. See "Litigation" section below for additional discussion of matters related to these penalties. These fines and penalties are unprecedented and were not consistent with historic enforcement practices of NCDEQ. Based on historic practices the expected liability of any existing notice of violations would not be material. Duke Energy Carolinas and Duke Energy Progress cannot predict whether the NCDEQ will assess future penalties related to existing NOVs and if such penalties would be material.
Asset retirement obligations recorded on the Duke Energy Carolinas and Duke Energy Progress Condensed Consolidated Balance Sheets at June 30, 2016 and December 31, 2015, include the legal obligation for closure of coal ash basins and the disposal of related ash as a result of the North Carolina Coal Ash Management Act of 2014, as amended (Coal Ash Act), and other agreements. In January 2016, NCDEQ published draft proposed risk classifications for sites not specifically delineated by the Coal Ash Act as high priority. These risk rankings were generally determined based on three primary criteria: structural integrity of the impoundments and impact to both surface and groundwater. NCDEQ categorized 12 basins at four sites as intermediate risk and four basins at 3 plants as low risk. Basins at high priority sites (Dan River, Riverbend, Asheville and Sutton) require closure through excavation including a combination of transferring the ash to an appropriate engineered landfill or conversion of the ash for beneficial use. Closure of high priority basins is required to be completed no later than August 1, 2019, except for Asheville which is required to be completed no later than August 1, 2022. Intermediate risk basins require closure through excavation including a combination of converting the basin to a lined industrial landfill, transferring of the ash to an appropriate engineered landfill or conversion of the ash for beneficial use. Closure of intermediate risk basins is required to be completed no later than December 31, 2024. Low risk basins require closure through either the combination of the installation and maintenance of a cap system and groundwater monitoring system designed to minimize infiltration and erosion or other closure options available to intermediate-risk basins. Closure of low risk basins is required to be completed no later than December 31, 2029. NCDEQ also categorized nine basins at six plants as “low-to-intermediate” risk, thereby not assigning a definitive risk ranking at that time. On May 18, 2016, NCDEQ issued new proposed risk classifications, ranking all originally proposed low risk and "low-intermediate" risk sites as intermediate.
On July 14, 2016, the Governor of North Carolina signed legislation which amends the Coal Ash Act and requires Duke Energy to undertake dam improvement projects and to provide access to a permanent alternative drinking water source to certain residents within a half mile of coal ash basin compliance boundaries and to certain other potentially impacted residents. The new legislation also ranks basins at the H.F. Lee, Cape Fear and Weatherspoon stations as intermediate risk consistent with Duke Energy's previously announced plans to excavate those basins. These specific intermediate basins require closure through excavation including a combination of transferring ash to an appropriate engineered landfill or conversion of the ash for beneficial use. Closure of these specific intermediate basins is required to be completed no later than August 1, 2028. Additionally, the new legislation requires the installation and operation of three large-scale coal ash beneficiation projects which are expected to produce reprocessed ash for use in the concrete industry. Closure of basins at sites with these beneficiation projects are required to be completed no later than December 31, 2029. Upon satisfactory completion of the dam improvement projects and installation of alternate drinking water sources by October 15, 2018, the legislation requires NCDEQ to reclassify intermediate risk sites, excluding H.F. Lee, Cape Fear and Weatherspoon, as low risk.
Per the Coal Ash Act, final proposed classifications were to be subject to Coal Ash Management Commission (Coal Ash Commission) approval. In March 2016, the Coal Ash Commission created by the Coal Ash Act was disbanded by the Governor of North Carolina based on a North Carolina Supreme Court ruling regarding the constitutionality of the body. The new legislation eliminates the Coal Ash Commission and transfers responsibility for ash basin closure oversight to the NCDEQ.

49


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

Estimated asset retirement obligations, including impacts from the legislation signed by the Governor of North Carolina on July 14, 2016, have been recognized based on the assigned risk categories or a probability weighting of potential closure methods. Actual closure costs incurred could be materially different from current estimates that form the basis of the recorded asset retirement obligations. Costs incurred have been deferred as regulatory assets and recovery will be pursued through the normal ratemaking process with federal and state utility commissions, which permit recovery of necessary and prudently incurred costs associated with Duke Energy’s regulated operations.
Coal Combustion Residuals
On April 17, 2015, the EPA published in the Federal Register a rule to regulate the disposal of CCR from electric utilities as solid waste. The federal regulation, which became effective in October 2015, classifies CCR as nonhazardous waste under Subtitle D of the Resource Conservation and Recovery Act and allows for beneficial use of CCR with some restrictions. The regulation applies to all new and existing landfills, new and existing surface impoundments receiving CCR and existing surface impoundments that are no longer receiving CCR but contain liquid located at stations currently generating electricity (regardless of fuel source). The rule establishes requirements regarding landfill design, structural integrity design and assessment criteria for surface impoundments, groundwater monitoring and protection procedures and other operational and reporting procedures to ensure the safe disposal and management of CCR. Various industry and environmental parties have appealed the EPA's CCR rule in the D.C. Circuit Court of Appeals. On April 18, 2016, the EPA filed an unopposed motion with the federal court to settle five issues raised in litigation. On June 14, 2016, the court approved the motion with respect to all of those issues. Duke Energy does not expect a material impact from the settlement or that it will result in additional asset retirement obligation adjustments.
In addition to the requirements of the federal CCR regulation, CCR landfills and surface impoundments will continue to be independently regulated by most states. As a result of the EPA rule, the Subsidiary Registrants recorded asset retirement obligation amounts during 2015.
LITIGATION
Duke Energy
Ash Basin Shareholder Derivative Litigation
Five shareholder derivative lawsuits were filed in Delaware Chancery Court relating to the release at Dan River and to the management of Duke Energy’s ash basins. On October 31, 2014, the five lawsuits were consolidated in a single proceeding titled In Re Duke Energy Corporation Coal Ash Derivative Litigation. On December 2, 2014, plaintiffs filed a Corrected Verified Consolidated Shareholder Derivative Complaint (Consolidated Complaint). The Consolidated Complaint names as defendants several current and former Duke Energy officers and directors (Duke Energy Defendants). Duke Energy is named as a nominal defendant.
The Consolidated Complaint alleges the Duke Energy Defendants breached their fiduciary duties by failing to adequately oversee Duke Energy’s ash basins and that these breaches of fiduciary duty may have contributed to the incident at Dan River and continued thereafter. The lawsuit also asserts claims against the Duke Energy Defendants for corporate waste (relating to the money Duke Energy has spent and will spend as a result of the fines, penalties and coal ash removal) and unjust enrichment (relating to the compensation and director remuneration that was received despite these alleged breaches of fiduciary duty). The lawsuit seeks both injunctive relief against Duke Energy and restitution from the Duke Energy Defendants. On January 21, 2015, the Duke Energy Defendants filed a Motion to Stay and an alternative Motion to Dismiss. On August 31, 2015, the court issued an order staying the case which was lifted on March 24, 2016. On April 22, 2016, plaintiffs filed an Amended Verified Consolidated Shareholder Derivative Complaint (Amended Complaint) making the same allegations as in the Consolidated Complaint. The Duke Energy Defendants filed a motion to dismiss the Amended Complaint on June 21, 2016.
On March 5, 2015, shareholder Judy Mesirov filed a shareholder derivative complaint (Mesirov Complaint) in North Carolina state court. The lawsuit, styled Mesirov v. Good, is similar to the consolidated derivative action pending in Delaware Chancery Court and was filed against the same current directors and former directors and officers as the Delaware litigation. Duke Energy Corporation, Duke Energy Progress and Duke Energy Carolinas are named as nominal defendants. The Mesirov Complaint alleges that the Duke Energy Board of Directors was aware of Clean Water Act (CWA) compliance issues and failures to maintain structures in ash basins, but that the Board of Directors did not require Duke Energy Carolinas and Duke Energy Progress to take action to remedy deficiencies. The Mesirov Complaint further alleges that the Board of Directors sanctioned activities to avoid compliance with the law by allowing improper influence of NCDEQ to minimize regulation and by opposing previously anticipated citizen suit litigation. The Mesirov Complaint seeks corporate governance reforms and damages relating to costs associated with the Dan River release, remediation of ash basins that are out of compliance with the CWA and defending and payment of fines, penalties and settlements relating to criminal and civil investigations and lawsuits. The case was stayed until July 1, 2016. On July 5, 2016, the plaintiff filed a Notice of Voluntary Dismissal Without Prejudice, closing this matter.
In addition to the above derivative complaints, in 2014, Duke Energy also received two shareholder litigation demand letters. The letters alleged that the members of the Board of Directors and certain officers breached their fiduciary duties by allowing the company to illegally dispose of and store coal ash pollutants. One of the letters also alleged a breach of fiduciary duty in the decision-making relating to the leadership changes following the close of the Progress Energy merger in July 2012.
By letter dated September 4, 2015, attorneys for the shareholders were informed that, on the recommendation of the Demand Review Committee formed to consider such matters, the Board of Directors concluded not to pursue potential claims against individuals. One of the shareholders, Mitchell Pinsly, sent a formal demand for records and Duke Energy responded to this request.

50


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

On October 30, 2015, shareholder Saul Bresalier filed a shareholder derivative complaint (Bresalier Complaint) in the U.S. District Court for the District of Delaware. The lawsuit alleges that several current and former Duke Energy officers and directors (Bresalier Defendants) breached their fiduciary duties in connection with coal ash environmental issues, the post-merger change in Chief Executive Officer (CEO) and oversight of political contributions. Duke Energy is named as a nominal defendant. The Bresalier Complaint contends that the Demand Review Committee failed to appropriately consider the shareholder’s earlier demand for litigation and improperly decided not to pursue claims against the Bresalier Defendants. The Bresalier Defendants filed a Motion to Dismiss the Bresalier litigation on January 15, 2016. In lieu of a response to the Motion to Dismiss, the plaintiff filed a Motion to Convert the Bresalier Defendants' Motion to Dismiss into a Motion for Summary Judgment and also for limited discovery. Following a hearing on June 15, 2016, the court denied the plaintiff's Motion to Convert and is requiring the parties to complete briefing on the Bresalier Defendants' Motion to Dismiss. On July 29, 2016, the Bresalier Defendants filed an Amended Motion to Dismiss.
It is not possible to predict whether Duke Energy will incur any liability or to estimate the damages, if any, it might incur in connection with these matters.
Progress Energy Merger Shareholder Litigation
On May 31, 2013, the Delaware Chancery Court consolidated four shareholder derivative lawsuits filed in 2012. The Court also appointed a lead plaintiff and counsel for plaintiffs and designated the case as In Re Duke Energy Corporation Derivative Litigation. The lawsuit names as defendants the 11 members of the Board of Directors who were also members of the pre-merger Board of Directors (Legacy Duke Energy Directors). Duke Energy is named as a nominal defendant. The case alleges claims for breach of fiduciary duties of loyalty and care in connection with the post-merger change in CEO. On December 10, 2015, the Legacy Duke Energy Directors filed a Motion to Dismiss the litigation. The court heard oral argument on the motion on May 9, 2016.
Two shareholder Derivative Complaints, filed in 2012 in federal district court in Delaware, were consolidated as Tansey v. Rogers, et al. The case alleges claims against the Legacy Duke Energy Directors for breach of fiduciary duty and waste of corporate assets, as well as claims under Section 14(a) and 20(a) of the Exchange Act. Duke Energy is named as a nominal defendant. On December 21, 2015, Plaintiff filed a Consolidated Amended Complaint asserting the same claims contained in the original complaints. The Legacy Duke Energy Directors filed a Motion to Dismiss on February 19, 2016. On March 18, 2016, the Chancery Court Plaintiffs moved to intervene in the Tansey proceeding, asking the federal district court to stay the federal litigation in favor of the Delaware Chancery litigation, which was denied on June 27, 2016. Oral argument on the Legacy Duke Energy Directors' Motion to Dismiss is scheduled for August 24, 2016.
It is not possible to predict whether Duke Energy will incur any liability or to estimate the damages, if any, it might incur in connection with the remaining litigation.
Price Reporting Cases
Duke Energy Trading and Marketing, LLC (DETM), a non-operating Duke Energy affiliate, was a defendant, along with numerous other energy companies, in four class action lawsuits and a fifth single-plaintiff lawsuit pending in a consolidated federal court proceeding in Nevada. Each of these lawsuits contains similar claims that defendants allegedly manipulated natural gas markets by various means, including providing false information to natural gas trade publications and entering into unlawful arrangements and agreements in violation of the antitrust laws of the respective states. Plaintiffs seek damages in unspecified amounts.
In February 2016, DETM reached agreements in principle to settle all of the pending lawsuits. Settlement of the single-plaintiff settlement was finalized and paid in March 2016. Settlement of the class action lawsuits are currently being finalized and will be subject to court approval. The settlement amounts are not material to Duke Energy.
Brazil Expansion Lawsuit
On August 9, 2011, the State of São Paulo sued Duke Energy International Geracao Paranapenema S.A. (DEIGP) in Brazilian state court. The lawsuit claims DEIGP is under a continuing obligation to expand installed generation capacity in the State of São Paulo by 15 percent pursuant to a stock purchase agreement under which DEIGP purchased generation assets from the state. On August 10, 2011, a judge granted an injunction ordering DEIGP to present a detailed expansion plan in satisfaction of the 15 percent obligation. DEIGP has previously taken a position that the expansion obligation is no longer viable given changes that have occurred in the electric energy sector since privatization. DEIGP submitted its proposed expansion plan on November 11, 2011, but reserved objections regarding enforceability. In January 2013, DEIGP filed appeals in the federal courts, which are still pending, regarding various procedural issues. A decision on the merits in the first instance court is also pending. It is not possible to predict whether Duke Energy will incur any liability or to estimate the damages, if any, it might incur in connection with this matter.
Brazil Generation
Record drought conditions in Brazil during 2014 and 2015 negatively impacted DEIGP. A number of electric generators have filed lawsuits seeking relief in the Brazilian courts to mitigate hydrological exposure and diminishing dispatch levels. Some courts have granted injunction orders to limit the financial exposure of certain generators. The implication of these orders is that other electricity market participants not covered by the injunctions may be required to compensate for the financial impact of the liability limitations. The Independent Power Producer Association (APINE) filed one such lawsuit on behalf of DEIGP and other hydroelectric generators against the Brazilian electric regulatory agency (ANEEL). On July 2, 2015, an injunction was granted in favor of APINE limiting the financial exposure of DEIGP and the other plaintiff generators, until the merits of the lawsuit are determined. ANEEL's appeal of the injunction was denied on December 18, 2015. The outcome of these lawsuits is uncertain. It is not possible to predict the impact to Duke Energy from the outcome of these matters.

51


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

Duke Energy Carolinas and Duke Energy Progress
NCDEQ Notices of Violation
In August 2014, NCDEQ issued an NOV for alleged groundwater violations at Duke Energy Progress' L.V. Sutton Plant. On March 10, 2015, NCDEQ issued a civil penalty of approximately $25 million to Duke Energy Progress for environmental damages related to the groundwater contamination at the L.V. Sutton Plant. On April 9, 2015, Duke Energy Progress filed a Petition for Contested Case hearing in the Office of Administrative Hearings. In February 2015, NCDEQ issued an NOV for alleged groundwater violations at Duke Energy Progress' Asheville Plant. Duke Energy Progress responded to NCDEQ regarding this NOV.
On September 29, 2015, Duke Energy Progress and Duke Energy Carolinas entered into a settlement agreement with NCDEQ resolving all former, current and future groundwater penalties at all Duke Energy Carolinas and Duke Energy Progress coal facilities in North Carolina. Under the agreement, Duke Energy Progress paid approximately $6 million and Duke Energy Carolinas paid approximately $1 million. In addition to these payments, Duke Energy Progress and Duke Energy Carolinas will accelerate remediation actions at the Sutton, Asheville, Belews Creek and H.F. Lee plants. The ALJ entered a consent order resolving the contested case relating to the Sutton Plant and NCDEQ rescinded the NOVs relating to alleged groundwater violations at both the Sutton and Asheville plants.
On October 13, 2015, the Southern Environmental Law Center (SELC), representing multiple conservation groups, filed a lawsuit in North Carolina Superior Court seeking judicial review of the order approving the settlement agreement with NCDEQ. The conservation groups contend that the ALJ exceeded his statutory authority in approving a settlement that provided for past, present, and future resolution of groundwater issues at facilities which were not at issue in the penalty appeal. On December 18, 2015, Duke Energy Carolinas and Duke Energy Progress filed a Motion to Dismiss the complaint. On February 12, 2016, the ALJ entered a new order clarifying that the dismissal of the contested case only applied to the specific issues before the ALJ in the Petition for Contested Case. On March 10, 2016, the court dismissed the SELC lawsuit based on the ALJ's entry of the new order.
On February 8, 2016, NCDEQ assessed a penalty of approximately $6.8 million, including enforcement costs, against Duke Energy Carolinas related to storm water pipes and associated discharges at the Dan River Steam Station. Duke Energy Carolinas recorded a charge in December 2015 for this penalty. In March 2016, Duke Energy Carolinas filed an appeal of this penalty. A summary judgment hearing is set for August 22, 2016, for this proceeding. Duke Energy Carolinas cannot predict the outcome of this matter.
NCDEQ State Enforcement Actions
In the first quarter of 2013, SELC sent notices of intent to sue Duke Energy Carolinas and Duke Energy Progress related to alleged CWA violations from coal ash basins at two of their coal-fired power plants in North Carolina. NCDEQ filed enforcement actions against Duke Energy Carolinas and Duke Energy Progress alleging violations of water discharge permits and North Carolina groundwater standards. The cases have been consolidated and are being heard before a single judge.
On August 16, 2013, NCDEQ filed an enforcement action against Duke Energy Carolinas and Duke Energy Progress related to their remaining plants in North Carolina, alleging violations of the CWA and violations of the North Carolina groundwater standards. Both of these cases have been assigned to the judge handling the enforcement actions discussed above. SELC is representing several environmental groups who have been permitted to intervene in these cases.
On July 10, 2015, Duke Energy Carolinas and Duke Energy Progress filed two Motions for Partial Summary Judgment in the case on the basis that there is no longer either a genuine controversy or disputed material facts about the relief for seven of the 14 North Carolina plants with coal ash basins. On September 14, 2015, the court granted the Motions for Partial Summary Judgment pending court approval of the terms through an order. On April 4, 2016, the court issued an order granting Duke Energy Progress' Motion for Partial Summary Judgment for cases involving the H.F. Lee, Cape Fear and Weatherspoon plants. On June 1, 2016, the court issued an order granting Duke Energy Carolinas' and Duke Energy Progress' Motion for Partial Summary Judgment for cases involving the Asheville, Dan River, Riverbend and Sutton plants. The litigation is concluded for these seven plants. Litigation continues for the remaining seven plants.
It is not possible to predict any liability or estimate any damages Duke Energy Carolinas or Duke Energy Progress might incur in connection with these matters.
Federal Citizens Suits
There are currently three cases filed in various North Carolina federal courts related to the Sutton, Buck and Mayo plants. Three other previously filed cases involving the Riverbend, Cape Fear and H.F. Lee plants were dismissed on June 7, 2016.
On September 12, 2013, Cape Fear River Watch, Inc., Sierra Club and Waterkeeper Alliance filed a citizen suit in the Federal District Court for the Eastern District of North Carolina. The lawsuit alleges unpermitted discharges to surface water and groundwater violations at the Sutton Plant. On June 9, 2014, the court granted Duke Energy Progress' request to dismiss the groundwater claims but rejected its request to dismiss the surface water claims. In response to a motion filed by the SELC on August 1, 2014, the court modified the original order to dismiss only the plaintiff's federal law claim based on hydrologic connections at Sutton Lake. The claims related to the alleged state court violations of the permits are back in the case. On August 26, 2015, the court suspended the proceedings until further order from the court.

52


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

On September 3, 2014, three citizen suits were filed by various environmental groups: (i) a citizen suit in the United States Court for the Middle District of North Carolina alleging unpermitted discharges to surface water and groundwater violations at the Cape Fear Plant; (ii) in the United States Court for the Eastern District of North Carolina alleging unpermitted discharges to surface water and groundwater violations at the H.F. Lee Plant; and (iii) in the United States Court for the Middle District of North Carolina alleging unpermitted discharges to surface water and groundwater violations at the Buck Steam Station. Motions to Stay or Dismiss the proceedings were filed in each of the three cases. The proceedings related to Cape Fear and H.F. Lee were dismissed on June 8, 2016, closing these matters. On October 20, 2015, the court issued an order denying the motions to stay or dismiss in the Buck proceedings. Duke Energy Carolinas' motion seeking appellate review of the District Court's decision relating to Buck was denied on January 29, 2016. The court has set an April 2017 trial date in the Buck proceeding.
On June 13, 2016, the Roanoke River Basin Association filed a federal citizen suit in the Middle District of North Carolina alleging unpermitted discharges to surface water and groundwater violations at the Mayo Plant. Duke Energy Progress expects to file a response to the complaint in third quarter of 2016.
It is not possible to predict whether Duke Energy Carolinas or Duke Energy Progress will incur any liability or to estimate the damages, if any, they might incur in connection with these matters.
Potential Groundwater Contamination Claims
Beginning in May 2015, a number of residents living in the vicinity of the North Carolina facilities with ash basins received letters from NCDEQ advising them not to drink water from the private wells on their land tested by NCDEQ as the samples were found to have certain substances at levels higher than the criteria set by the North Carolina Department of Health and Human Services (DHHS). The criteria, in some cases, are considerably more stringent than federal drinking water standards established to protect human health and welfare. The Coal Ash Act requires additional groundwater monitoring and assessments for each of the 14 coal-fired plants in North Carolina, including sampling of private water supply wells. The data gathered through these Comprehensive Site Assessments (CSAs) will be used by NCDEQ to determine whether the water quality of these private water supply wells has been adversely impacted by the ash basins. Duke Energy has submitted CSAs documenting the results of extensive groundwater monitoring around coal ash basins at all 14 of the plants with coal ash basins. Generally, the data gathered through the installation of new monitoring wells and soil and water samples across the state have been consistent with historical data provided to state regulators over many years. The DHHS and NCDEQ sent follow-up letters on October 15, 2015, to residents near coal ash basins who have had their wells tested, stating that private well samplings at a considerable distance from coal ash impoundments, as well as some municipal water supplies, contain similar levels of vanadium and hexavalent chromium which leads investigators to believe these constituents are naturally occurring. In March 2016, DHHS rescinded the advisories. It is not possible to estimate the maximum exposure of loss, if any, that may occur in connection with claims which might be made by these residents.
Asbestos-related Injuries and Damages Claims
Duke Energy Carolinas has experienced numerous claims for indemnification and medical cost reimbursement related to asbestos exposure. These claims relate to damages for bodily injuries alleged to have arisen from exposure to or use of asbestos in connection with construction and maintenance activities conducted on its electric generation plants prior to 1985. As of June 30, 2016, there were 89 asserted claims for non-malignant cases with the cumulative relief sought of up to $24 million, and 83 asserted claims for malignant cases with the cumulative relief sought of up to $15 million. Based on Duke Energy Carolinas’ experience, it is expected that the ultimate resolution of most of these claims likely will be less than the amount claimed.
Duke Energy Carolinas has recognized asbestos-related reserves of $515 million at June 30, 2016 and $536 million at December 31, 2015. These reserves are classified in Other within Deferred Credits and Other Liabilities and Other within Current Liabilities on the Condensed Consolidated Balance Sheets. These reserves are based upon the minimum amount of the range of loss for current and future asbestos claims through 2033, are recorded on an undiscounted basis and incorporate anticipated inflation. In light of the uncertainties inherent in a longer-term forecast, management does not believe they can reasonably estimate the indemnity and medical costs that might be incurred after 2033 related to such potential claims. It is possible Duke Energy Carolinas may incur asbestos liabilities in excess of the recorded reserves.
Duke Energy Carolinas has third-party insurance to cover certain losses related to asbestos-related injuries and damages above an aggregate self-insured retention. Duke Energy Carolinas’ cumulative payments began to exceed the self-insurance retention in 2008. Future payments up to the policy limit will be reimbursed by the third-party insurance carrier. The insurance policy limit for potential future insurance recoveries indemnification and medical cost claim payments is $847 million in excess of the self-insured retention. Receivables for insurance recoveries were $600 million at June 30, 2016 and $599 million at December 31, 2015. These amounts are classified in Other within Investments and Other Assets and Receivables on the Condensed Consolidated Balance Sheets. Duke Energy Carolinas is not aware of any uncertainties regarding the legal sufficiency of insurance claims. Duke Energy Carolinas believes the insurance recovery asset is probable of recovery as the insurance carrier continues to have a strong financial strength rating.
Duke Energy Florida
Class Action Lawsuit
On February 22, 2016, a lawsuit was filed in the U.S. District Court for the Southern District of Florida on behalf of a putative class of Duke Energy Florida and FP&L’s customers in Florida. The suit alleges the State of Florida’s nuclear power plant cost recovery statutes (NCRS) are unconstitutional and pre-empted by federal law. Plaintiffs claim they are entitled to repayment of all money paid by customers of Duke Energy Florida and FP&L as a result of the NCRS, as well as an injunction against any future charges under those statutes. The constitutionality of the NCRS has been challenged unsuccessfully in a number of prior cases on alternative grounds. Duke Energy Florida and FP&L filed motions to dismiss the complaint on May 5, 2016. Duke Energy Florida cannot predict the outcome of this matter.

53


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

Westinghouse Contract Litigation
On March 28, 2014, Duke Energy Florida filed a lawsuit against Westinghouse in the U.S. District Court for the Western District of North Carolina. The lawsuit seeks recovery of $54 million in milestone payments in excess of work performed under the terminated Engineering, Procurement and Construction agreement (EPC) for Levy as well as a determination by the court of the amounts due to Westinghouse as a result of the termination of the EPC. Duke Energy Florida recognized an exit obligation as a result of the termination of the EPC contract.
On March 31, 2014, Westinghouse filed a lawsuit against Duke Energy Florida in U.S. District Court for the Western District of Pennsylvania. The Pennsylvania lawsuit alleged damages under the EPC in excess of $510 million for engineering and design work, costs to end supplier contracts and an alleged termination fee.
On June 9, 2014, the judge in the North Carolina case ruled that the litigation will proceed in the Western District of North Carolina. In November 2014, Westinghouse filed a Motion for Partial Judgment on the pleadings, which was denied on March 30, 2015. The trial date is set for October 17, 2016. On July 11, 2016, Duke Energy Florida and Westinghouse filed separate Motions for Summary Judgment. It is not possible to predict the outcome of the litigation, whether Duke Energy Florida will ultimately have any liability for terminating the EPC contract or to estimate the damages, if any, it might incur in connection with these matters. Ultimate resolution of these matters could have a material effect on the results of operations, financial position or cash flows of Duke Energy Florida. However, appropriate regulatory recovery will be pursued for the retail portion of any costs incurred in connection with such resolution.
Duke Energy Ohio
Antitrust Lawsuit
In January 2008, four plaintiffs, including individual, industrial and nonprofit customers, filed a lawsuit against Duke Energy Ohio in federal court in the Southern District of Ohio. Plaintiffs alleged Duke Energy Ohio conspired to provide inequitable and unfair price advantages for certain large business consumers by entering into nonpublic option agreements in exchange for their withdrawal of challenges to Duke Energy Ohio’s Rate Stabilization Plan implemented in early 2005. In March 2014, a federal judge certified this matter as a class action. Plaintiffs alleged claims of antitrust violations under the federal Robinson Patman Act as well as fraud and conspiracy allegations under the federal Racketeer Influenced and Corrupt Organizations statute and the Ohio Corrupt Practices Act.
During 2015, the parties received preliminary court approval of a settlement agreement. Duke Energy Ohio included a litigation reserve of $81 million in Other within Current Liabilities on the Consolidated Balance Sheet at December 31, 2015. Duke Energy Ohio recognized pretax charges of $71 million and $81 million in (Loss) Income from Discontinued Operations, net of tax in the Condensed Consolidated Statements of Operations and Comprehensive Income for the three and six months ended June 30, 2015, respectively. The settlement agreement was approved at a federal court hearing on April 19, 2016.
W.C. Beckjord Fuel Release
On August 18, 2014, approximately 9,000 gallons of fuel oil were inadvertently discharged into the Ohio River during a fuel oil transfer at the W.C. Beckjord generating station. The Ohio Environmental Protection Agency (Ohio EPA) issued a NOV related to the discharge. Duke Energy Ohio is cooperating with the Ohio EPA, the EPA and the U.S. Attorney for the Southern District of Ohio. No NOV has been issued by the EPA and no penalty has been assessed. Total repair and remediation costs related to the release were not material. Other costs related to the release, including state or federal civil or criminal enforcement proceedings, cannot be reasonably estimated at this time.
Other Litigation and Legal Proceedings
The Duke Energy Registrants are involved in other legal, tax and regulatory proceedings arising in the ordinary course of business, some of which involve significant amounts. The Duke Energy Registrants believe the final disposition of these proceedings will not have a material effect on their results of operations, cash flows or financial position.
The table below presents recorded reserves based on management’s best estimate of probable loss for legal matters, excluding asbestos related reserves and the exit obligation discussed above related to the termination of an EPC contract. Reserves are classified on the Condensed Consolidated Balance Sheets in Other within Deferred Credits and Other Liabilities and Accounts payable and Other within Current Liabilities. The reasonably possible range of loss in excess of recorded reserves is not material, other than as described above.
(in millions)
June 30, 2016

 
December 31, 2015

Reserves for Legal Matters
 
 
 
Duke Energy
$
110

 
$
166

Duke Energy Carolinas
14

 
11

Progress Energy
52

 
54

Duke Energy Progress
6

 
6

Duke Energy Florida
30

 
31

Duke Energy Ohio
4

 
80


54


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

OTHER COMMITMENTS AND CONTINGENCIES
General
As part of their normal business, the Duke Energy Registrants are party to various financial guarantees, performance guarantees and other contractual commitments to extend guarantees of credit and other assistance to various subsidiaries, investees and other third parties. These guarantees involve elements of performance and credit risk, which are not fully recognized on the Condensed Consolidated Balance Sheets and have unlimited maximum potential payments. However, the Duke Energy Registrants do not believe these guarantees will have a material effect on their results of operations, cash flows or financial position.
In addition, the Duke Energy Registrants enter into various fixed-price, noncancelable commitments to purchase or sell power, take-or-pay arrangements, transportation, or throughput agreements and other contracts that may or may not be recognized on their respective Condensed Consolidated Balance Sheets. Some of these arrangements may be recognized at fair value on their respective Condensed Consolidated Balance Sheets if such contracts meet the definition of a derivative and the normal purchase/normal sale (NPNS) exception does not apply. In most cases, the Duke Energy Registrants’ purchase obligation contracts contain provisions for price adjustments, minimum purchase levels and other financial commitments.
6. DEBT AND CREDIT FACILITIES
SUMMARY OF SIGNIFICANT DEBT ISSUANCES
The following table summarizes significant debt issuances (in millions).
 
 
 
 
 
Six Months Ended
 
 
 
 
 
June 30, 2016
 
 
 
 
 
 
 
Duke

 
Duke

 
Duke

 
Duke

 
Duke

 
Maturity
 
Interest

 
Duke

 
Energy

 
Energy

 
Energy

 
Energy

 
Energy

Issuance Date
Date
 
Rate

 
Energy

 
(Parent)

 
Carolinas

 
Florida

 
Ohio

 
Indiana

Unsecured
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
April 2016(a)
April 2023
 
2.875
%
 
$
350

 
$
350

 
$

 
$

 
$

 
$

First Mortgage Bonds
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
March 2016(b)
March 2023

2.500
%
 
500

 

 
500

 

 

 

March 2016(b)
March 2046

3.875
%
 
500

 

 
500

 

 

 

May 2016(c)
May 2046

3.750
%

500



 

 

 

 
500

June 2016(b)
June 2046

3.700
%

250



 

 

 
250

 

Secured Debt



 


 
 
 


 
 
 
 
 
 
June 2016(d)
March 2020

1.196
%
 
183

 

 

 
183

 

 

June 2016(d)
September 2022

1.731
%

150



 

 
150

 

 

June 2016(d)
September 2029
 
2.538
%
 
436

 

 

 
436

 

 

June 2016(d)
March 2033

2.858
%
 
250

 

 

 
250

 

 

June 2016(d)
September 2036

3.112
%
 
275

 

 

 
275

 

 

Total issuances
 
 
 
 
$
3,394

 
$
350


$
1,000

 
$
1,294


$
250


$
500

(a)
Proceeds were used to pay down outstanding commercial paper and for general corporate purposes.
(b)
Proceeds were used to fund capital expenditures for ongoing construction, capital maintenance and for general corporate purposes.
(c)
Proceeds were used to repay $325 million of unsecured debt due June 2016, $150 million of first mortgage bonds due July 2016 and for general corporate purposes.
(d)
Proceeds from the nuclear asset recovery bonds issued by DEFPF, a bankruptcy remote subsidiary of Duke Energy Florida, were used to acquire nuclear asset-recovery property from its parent, Duke Energy Florida. The nuclear asset-recovery bonds are payable only from and secured by the nuclear asset-recovery property. DEFPF is consolidated for financial reporting purposes; however, the nuclear asset-recovery bonds do not constitute a debt, liability or other legal obligation of, or interest in, Duke Energy Florida or any of its affiliates other than DEFPF. The assets of DEFPF, including the nuclear asset-recovery property, are not available to pay creditors of Duke Energy Florida or any of its affiliates. Duke Energy Florida used the proceeds from the sale to repay short-term borrowings under the intercompany money pool borrowing arrangement and make an equity distribution of $649 million to the ultimate parent, Duke Energy (Parent), which repaid short-term borrowings. The nuclear asset-recovery bonds are sequential pay amortizing bonds. The maturity date above represents the scheduled final maturity date for the bonds. See Notes 4 and 12 for additional information.

55


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

CURRENT MATURITIES OF LONG-TERM DEBT
The following table shows the significant components of Current maturities of long-term debt on the Condensed Consolidated Balance Sheets. The Duke Energy Registrants currently anticipate satisfying these obligations with cash on hand and proceeds from additional borrowings.
(in millions)
Maturity Date
 
Interest Rate

 
June 30, 2016

Unsecured Debt
 
 
 
 
 
Duke Energy (Parent)
November 2016
 
2.150
%
 
$
500

Duke Energy (Parent)
April 2017
 
1.009
%
 
400

Duke Energy
May 2017
 
15.530
%
 
56

Secured Debt
 
 
 
 
 
Duke Energy
June 2017
 
2.075
%
 
45

First Mortgage Bonds
 
 
 
 
 
Duke Energy Indiana
July 2016
 
0.979
%
 
150

Duke Energy Carolinas
December 2016
 
1.750
%
 
350

Duke Energy Progress
March 2017
 
0.880
%
 
250

Tax-exempt Bonds
 
 
 
 
 
Duke Energy Carolinas
February 2017
 
3.600
%
 
77

Duke Energy Ohio(a)
August 2027
 
1.280
%
 
50

Duke Energy Indiana(b)
May 2035
 
1.092
%
 
44

Other(c)
 
 
 
 
420

Current maturities of long-term debt
 
 
 
 
$
2,342

(a)
Represents Duke Energy Kentucky's bonds with a mandatory put in December 2016.
(b)
The bonds have a mandatory put in December 2016.
(c)
Includes capital lease obligations, amortizing debt and small bullet maturities.
AVAILABLE CREDIT FACILITIES
Master Credit Facility
Duke Energy has a Master Credit Facility with a capacity of $7.5 billion through January 2020. The Duke Energy Registrants, excluding Progress Energy (Parent), have borrowing capacity under the Master Credit Facility up to a specified sublimit for each borrower. Duke Energy has the unilateral ability at any time to increase or decrease the borrowing sublimits of each borrower, subject to a maximum sublimit for each borrower. The amount available under the Master Credit Facility has been reduced to backstop issuances of commercial paper, certain letters of credit and variable-rate demand tax-exempt bonds that may be put to the Duke Energy Registrants at the option of the holder. Duke Energy Carolinas and Duke Energy Progress are also required to each maintain $250 million of available capacity under the Master Credit Facility as security to meet obligations under plea agreements reached with the U.S. Department of Justice in 2015 related to violations at North Carolina facilities with ash basins. The table below includes the current borrowing sublimits and available capacity under the Master Credit Facility.
 
June 30, 2016
 


 
Duke

 
Duke

 
Duke

 
Duke

 
Duke

 
Duke

 
Duke

 
Energy

 
Energy

 
Energy

 
Energy

 
Energy

 
Energy

(in millions)
Energy

 
(Parent)

 
Carolinas

 
Progress

 
Florida

 
Ohio

 
Indiana

Facility size(a)
$
7,500

 
$
3,475

 
$
800

 
$
1,000

 
$
1,200

 
$
425

 
$
600

Reduction to backstop issuances
 
 
 
 
 
 
 
 
 
 
 
 
 
Commercial paper(b)
(1,673
)
 
(992
)
 
(300
)
 
(159
)
 
(47
)
 
(25
)
 
(150
)
Outstanding letters of credit
(77
)
 
(70
)
 
(4
)
 
(2
)
 
(1
)
 

 

Tax-exempt bonds
(116
)
 

 
(35
)
 

 

 

 
(81
)
Coal ash set-aside
(500
)
 

 
(250
)
 
(250
)
 

 

 

Available capacity
$
5,134


$
2,413


$
211


$
589


$
1,152


$
400


$
369

(a)
Represents the sublimit of each borrower.
(b)
Duke Energy issued $625 million of commercial paper and loaned the proceeds through the money pool to Duke Energy Carolinas, Duke Energy Progress, Duke Energy Ohio and Duke Energy Indiana. The balances are classified as Long-Term Debt Payable to Affiliated Companies in the Condensed Consolidated Balance Sheets.

56


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

Piedmont Bridge Facility
In connection with the Merger Agreement with Piedmont, Duke Energy entered into a $4.9 billion Bridge Facility with Barclays. The Bridge Facility, if drawn upon, may be used (i) to fund the cash consideration for the transaction and (ii) to pay certain fees and expenses in connection with the transaction. In November 2015, Barclays syndicated its commitment under the Bridge Facility to a broader group of lenders. Duke Energy does not expect to draw upon the Bridge Facility. The amount of the Bridge Facility is reduced by any financings related to the Piedmont acquisition entered into by Duke Energy, and has accordingly been reduced to approximately $3.2 billion as a result of the Equity Forwards described in Note 13 and $1 billion of commitments under a term loan amended and restated as of August 1, 2016, described below. Refer to Note 2 for additional information on the Piedmont acquisition.
Term Loan Facility
On February 22, 2016, Duke Energy entered into a six-month term loan facility with commitments totaling $1.0 billion (the February 2016 Term Loan). As of June 30, 2016, $100 million was outstanding under the February 2016 Term Loan. On August 1, 2016, Duke Energy and each of the lenders under the February 2016 Term Loan amended and restated certain terms of this facility, resulting in aggregate commitments of $1.5 billion and extending the maturity date to July 31, 2017. 
As of August 1, 2016, $100 million has been drawn under the amended and restated term loan (the August 2016 Term Loan). The remaining $1.4 billion of commitments under the August 2016 Term Loan can be drawn in up to two separate borrowings, which must occur no later than 90 calendar days following August 1, 2016. Any borrowings under the August 2016 Term Loan will be used to manage short-term liquidity, including funding a portion of the Piedmont acquisition, and for general corporate purposes. The terms and conditions of the August 2016 Term Loan are generally consistent with those governing Duke Energy’s Master Credit Facility.
Solar Facilities Financing
In August 2016, Emerald State Solar, LLC, an indirect wholly owned subsidiary of Duke Energy, entered into a portfolio financing of approximately 22 North Carolina Solar facilities. The $333 million term loan facility consists of Tranche A of $228 million due in June 2034 secured by substantially all the assets of the solar facilities and Tranche B of $105 million due in June 2020 secured by an Equity Contribution Agreement with Duke Energy. The initial interest rate on the loans is six months London Interbank Offered Rate (LIBOR) plus an applicable margin. The initial applicable margin is 1.75 percent with 0.125 percent increases every three years thereafter. In connection with this debt issuance, Emerald State Solar, LLC entered into two interest rate swaps to convert the substantial majority of the loan interest payments from variable rates to fixed rates of approximately 1.81 percent for Tranche A and 1.38 percent for Tranche B, plus the applicable margin.
7. GOODWILL AND INTANGIBLE ASSETS
GOODWILL
The following table presents goodwill by reportable operating segment for Duke Energy.
Duke Energy
 
Regulated

 
International

 
Commercial

 
 
(in millions)
Utilities

 
Energy

 
Portfolio

 
Total

Goodwill at December 31, 2015
$
15,950

 
$
271

 
$
122

 
$
16,343

Foreign exchange changes

 
14

 

 
14

Goodwill at June 30, 2016
$
15,950

 
$
285

 
$
122

 
$
16,357

Duke Energy Ohio
Duke Energy Ohio's Goodwill balance of $920 million is included in the Regulated Utilities operating segment and presented net of accumulated impairment charges of $216 million on the Condensed Consolidated Balance Sheets at June 30, 2016 and December 31, 2015.
Progress Energy
Progress Energy's Goodwill is included in the Regulated Utilities operating segment and there are no accumulated impairment charges.

57


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

8. RELATED PARTY TRANSACTIONS
The Subsidiary Registrants engage in related party transactions in accordance with applicable state and federal commission regulations. Refer to the Condensed Consolidated Balance Sheets of the Subsidiary Registrants for balances due to or due from related parties. Material amounts related to transactions with related parties included in the Condensed Consolidated Statements of Operations and Comprehensive Income are presented in the following table.
 
Three Months Ended June 30,
 
Six Months Ended June 30,
(in millions)
2016

 
2015

 
2016

 
2015

Duke Energy Carolinas
 
 
 
 
 
 
 
Corporate governance and shared service expenses(a)
$
199

 
$
202

 
$
416

 
$
421

Indemnification coverages(b)
5

 
6

 
11

 
12

JDA revenue(c)
2

 
14

 
11

 
40

JDA expense(c)
50

 
38

 
91

 
95

Progress Energy
 
 
 
 
 
 
 
Corporate governance and shared service expenses(a)
$
160

 
$
172

 
$
334

 
$
339

Indemnification coverages(b)
9

 
9

 
17

 
19

JDA revenue(c)
50

 
38

 
91

 
95

JDA expense(c)
2

 
14

 
11

 
40

Duke Energy Progress
 
 
 
 
 
 
 
Corporate governance and shared service expenses(a)
$
89

 
$
93

 
$
189

 
$
194

Indemnification coverages(b)
4

 
4

 
7

 
8

JDA revenue(c)
50

 
38

 
91

 
95

JDA expense(c)
2

 
14

 
11

 
40

Duke Energy Florida
 
 
 
 
 
 
 
Corporate governance and shared service expenses(a)
$
71

 
$
79

 
$
145

 
$
145

Indemnification coverages(b)
5

 
5

 
10

 
11

Duke Energy Ohio
 
 
 
 
 
 
 
Corporate governance and shared service expenses(a)
$
87

 
$
103

 
$
172

 
$
188

Indemnification coverages(b)
1

 
1

 
2

 
4

Duke Energy Indiana
 
 
 
 
 
 
 
Corporate governance and shared service expenses(a)
$
89

 
$
83

 
$
183

 
$
172

Indemnification coverages(b)
2

 
2

 
4

 
4

(a)
The Subsidiary Registrants are charged their proportionate share of corporate governance and other shared services costs, primarily related to human resources and employee benefits, information technology, legal and accounting fees, as well as other third-party costs. These amounts are recorded in Operation, maintenance and other on the Condensed Consolidated Statements of Operations and Comprehensive Income.
(b)
The Subsidiary Registrants incur expenses related to certain indemnification coverages through Bison, Duke Energy’s wholly owned captive insurance subsidiary. These expenses are recorded in Operation, maintenance and other on the Condensed Consolidated Statements of Operations and Comprehensive Income.
(c)
Duke Energy Carolinas and Duke Energy Progress participate in a JDA which allows the collective dispatch of power plants between the service territories to reduce customer rates. Revenues from the sale of power under the JDA are recorded in Operating Revenues on the Condensed Consolidated Statements of Operations and Comprehensive Income. Expenses from the purchase of power under the JDA are recorded in Fuel used in electric generation and purchased power on the Condensed Consolidated Statements of Operations and Comprehensive Income.
In addition to the amounts presented above, the Subsidiary Registrants record the impact on net income of other affiliate transactions, including rental of office space, participation in a money pool arrangement, other operational transactions and their proportionate share of certain charged expenses. See Note 6 to the Consolidated Financial Statements in the Annual Report on Form 10-K for more information regarding money pool. The net impact of these transactions was not material for the three and six months ended June 30, 2016 and 2015 for the Subsidiary Registrants.
As discussed in Note 12, certain trade receivables have been sold by Duke Energy Ohio and Duke Energy Indiana to CRC, an affiliate formed by a subsidiary of Duke Energy. The proceeds obtained from the sales of receivables are largely cash but also include a subordinated note from the affiliate for a portion of the purchase price.
Duke Energy Ohio's nonregulated indirect subsidiary, Duke Energy Commercial Asset Management (DECAM), owned generating plants included in the Disposal Group sold to Dynegy on April 2, 2015. On April 1, 2015, Duke Energy Ohio distributed its indirect ownership interest in DECAM to a Duke Energy subsidiary and non-cash settled DECAM's intercompany loan payable of $294 million. Refer to Note 2 for further information on the sale of the Disposal Group.

58


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

Intercompany Income Taxes
Duke Energy and the Subsidiary Registrants file a consolidated federal income tax return and other state and jurisdictional returns. The Subsidiary Registrants have a tax sharing agreement with Duke Energy for the allocation of consolidated tax liabilities and benefits. Income taxes recorded represent amounts the Subsidiary Registrants would incur as separate C-Corporations. The following table includes the balance of intercompany income tax receivables and payables for the Subsidiary Registrants.
 
Duke

 
Duke

Duke

Duke

Duke

 
Energy

Progress

Energy

Energy

Energy

Energy

(in millions)
Carolinas

Energy

Progress

Florida

Ohio

Indiana

June 30, 2016
 
 
 
 
 
 
Intercompany income tax receivable
$
10

$
90

$

$

$
15

$
6

Intercompany income tax payable


11

48



 
 
 
 
 
 
 
December 31, 2015
 
 
 
 
 
 
Intercompany income tax receivable
$
122

$
120

$
104

$

$
54

$

Intercompany income tax payable



96


47

9. DERIVATIVES AND HEDGING
The Duke Energy Registrants use commodity and interest rate contracts to manage commodity price risk and interest rate risk. The primary use of commodity derivatives is to hedge the generation portfolio against changes in the prices of electricity and natural gas. Interest rate swaps are used to manage interest rate risk associated with borrowings.
All derivative instruments not identified as NPNS are recorded at fair value as assets or liabilities on the Condensed Consolidated Balance Sheets. Cash collateral related to derivative instruments executed under master netting arrangements is offset against the collateralized derivatives on the Condensed Consolidated Balance Sheets. The cash impacts of settled derivatives are recorded as operating activities on the Condensed Consolidated Statements of Cash Flows.
INTEREST RATE RISK
The Duke Energy Registrants are exposed to changes in interest rates as a result of their issuance or anticipated issuance of variable-rate and fixed-rate debt and commercial paper. Interest rate risk is managed by limiting variable-rate exposures to a percentage of total debt and by monitoring changes in interest rates. To manage risk associated with changes in interest rates, the Duke Energy Registrants may enter into interest rate swaps, U.S. Treasury lock agreements and other financial contracts. In anticipation of certain fixed-rate debt issuances, a series of forward-starting interest rate swaps may be executed to lock in components of current market interest rates. These instruments are later terminated prior to or upon the issuance of the corresponding debt.
Cash Flow Hedges
For a derivative designated as hedging the exposure to variable cash flows of a future transaction, referred to as a cash flow hedge, the effective portion of the derivative's gain or loss is initially reported as a component of other comprehensive income and subsequently reclassified into earnings once the future transaction affects earnings. Amounts for interest rate contracts are reclassified to earnings as interest expense over the term of the related debt. Gains and losses reclassified out of Accumulated other comprehensive income (AOCI) for the three and six months ended June 30, 2016, were not material. Duke Energy's interest rate derivatives designated as hedges include interest rate swaps used to hedge existing debt within the International Energy and Renewables' businesses.
Undesignated Contracts
Undesignated contracts include contracts not designated as a hedge because they are accounted for under regulatory accounting and contracts that do not qualify for hedge accounting.
Duke Energy’s interest rate swaps for its Regulated Utilities operations employ regulatory accounting. With regulatory accounting, the mark-to-market gains or losses on the swaps are deferred as regulatory liabilities or regulatory assets, respectively. Regulatory assets and liabilities are amortized consistent with the treatment of the related costs in the ratemaking process. The accrual of interest on the swaps is recorded as Interest Expense.
As of June 30, 2016, Duke Energy has entered into $1.4 billion of forward-starting interest rate swaps to manage interest rate exposure for the expected financing of the Piedmont acquisition. The swaps do not qualify for hedge accounting and are marked-to-market, with any gains or losses included within earnings. Unrealized losses on the swaps of $75 million and $168 million were included within Interest Expense on the Condensed Consolidated Statements of Operations for the three and six months ended June 30, 2016. The swaps will be terminated in conjunction with the acquisition financing. See Note 2 for additional information related to the Piedmont acquisition.

59


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

The following table shows notional amounts of outstanding derivatives related to interest rate risk.
 
June 30, 2016
 
 
 
Duke

 
 
 
Duke

 
Duke

 
Duke

 
Duke

 
Energy

 
Progress

 
Energy

 
Energy

 
Energy

(in millions)
Energy

 
Carolinas

 
Energy

 
Progress

 
Florida

 
Ohio

Cash flow hedges(a)
$
663

 
$

 
$

 
$

 
$

 
$

Undesignated contracts
2,327

 
400

 
500

 
250

 
250

 
27

Total notional amount
$
2,990


$
400


$
500


$
250


$
250


$
27

 
December 31, 2015
 
 
 
Duke

 
 
 
Duke

 
Duke

 
Duke

 
Duke

 
Energy

 
Progress

 
Energy

 
Energy

 
Energy

(in millions)
Energy

 
Carolinas

 
Energy

 
Progress

 
Florida

 
Ohio

Cash flow hedges(a)
$
700

 
$

 
$

 
$

 
$

 
$

Undesignated contracts
1,827

 
400

 
500

 
250

 
250

 
27

Total notional amount
$
2,527

 
$
400

 
$
500

 
$
250

 
$
250

 
$
27

(a)
Duke Energy includes amounts related to consolidated VIEs of $463 million at June 30, 2016 and $497 million at December 31, 2015.
COMMODITY PRICE RISK
The Duke Energy Registrants are exposed to the impact of changes in the prices of electricity, coal and natural gas. Exposure to commodity price risk is influenced by a number of factors including the term of contracts, the liquidity of markets and delivery locations.
Regulated public utilities may have cost-based rate regulations and various other cost recovery mechanisms that result in a limited exposure to market volatility of commodity fuel prices. Financial derivative contracts, where approved by the respective state regulatory commissions, can be used to manage the risk of price volatility. At June 30, 2016, substantially all of Duke Energy's open commodity derivative instruments were undesignated because they are accounted for under regulatory accounting. Mark-to-market gains or losses on contracts that use regulatory accounting are deferred as regulatory liabilities or regulatory assets, respectively. Undesignated contracts expire as late as 2020.
The Subsidiary Registrants utilize cost-tracking mechanisms, commonly referred to as fuel adjustment clauses. These clauses allow for the recovery of fuel and fuel-related costs, including settlements of undesignated derivatives for fuel commodities, and portions of purchased power costs through surcharges on customer rates. The difference between the costs incurred and the surcharge revenues is recorded as an adjustment to Fuel used in electric generation and purchased power – regulated or as Operating Revenues: Regulated electric on the Condensed Consolidated Statements of Operations, with an offsetting impact on regulatory assets or liabilities. Therefore, due to the regulatory accounting followed by the Subsidiary Registrants for undesignated derivatives, realized and unrealized gains and losses on undesignated commodity derivatives do not have an immediate impact on reported net income.
Volumes
The tables below show volumes of outstanding commodity derivatives. Amounts disclosed represent the absolute value of notional volumes of commodity contracts excluding NPNS. The Duke Energy Registrants have netted contractual amounts where offsetting purchase and sale contracts exist with identical delivery locations and times of delivery. Where all commodity positions are perfectly offset, no quantities are shown.
 
June 30, 2016
 
 
 
Duke

 
 
 
Duke

 
Duke

 
Duke

 
Duke

 
Duke

 
Energy

 
Progress

 
Energy

 
Energy

 
Energy

 
Energy

 
Energy

 
Carolinas

 
Energy

 
Progress

 
Florida

 
Ohio

 
Indiana

Electricity (gigawatt-hours)
7

 

 

 

 

 

 
7

Natural gas (millions of decatherms)
418

 
80

 
338

 
124

 
214

 

 

 
December 31, 2015
 
 
 
Duke

 
 
 
Duke

 
Duke

 
Duke

 
Duke

 
Duke

 
Energy

 
Progress

 
Energy

 
Energy

 
Energy

 
Energy

 
Energy

 
Carolinas

 
Energy

 
Progress

 
Florida

 
Ohio

 
Indiana

Electricity (gigawatt-hours)
70

 

 

 

 

 
34

 
36

Natural gas (millions of decatherms)
398

 
66

 
332

 
117

 
215

 

 


60


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

LOCATION AND FAIR VALUE OF DERIVATIVE ASSETS AND LIABILITIES RECOGNIZED IN THE CONDENSED CONSOLIDATED BALANCE SHEETS
The following tables show the fair value and balance sheet location of derivative instruments. Although derivatives subject to master netting arrangements are netted on the Condensed Consolidated Balance Sheets, the fair values presented below are shown gross and cash collateral on the derivatives has not been netted against the fair values shown.
Derivative Assets
 
June 30, 2016
 
 
 
 
Duke

 
 
 
Duke

 
Duke

 
Duke

 
Duke

 
 
Duke

 
Energy

 
Progress

 
Energy

 
Energy

 
Energy

 
Energy

(in millions)
 
Energy

 
Carolinas

 
Energy

 
Progress

 
Florida

 
Ohio

 
Indiana

Commodity Contracts
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Not Designated as Hedging Instruments
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Current
 
$
64

 
$
8

 
$
20

 
$
8

 
$
12

 
$
5

 
$
31

Noncurrent
 
28

 
10

 
18

 
10

 
8

 

 

Total Derivative Assets – Commodity Contracts
 
$
92

 
$
18

 
$
38

 
$
18

 
$
20

 
$
5

 
$
31

Interest Rate Contracts
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Not Designated as Hedging Instruments
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Current
 
$
3

 
$

 
$
3

 
$
1

 
$
2

 
$

 
$

Noncurrent
 
13

 

 
13

 
6

 
7

 

 

Total Derivative Assets – Interest Rate Contracts
 
$
16

 
$

 
$
16

 
$
7

 
$
9

 
$

 
$

Total Derivative Assets
 
$
108


$
18


$
54


$
25


$
29


$
5


$
31

Derivative Liabilities
 
June 30, 2016
 
 
 
 
Duke

 
 
 
Duke

 
Duke

 
Duke

 
Duke

 
 
Duke

 
Energy

 
Progress

 
Energy

 
Energy

 
Energy

 
Energy

(in millions)
 
Energy

 
Carolinas

 
Energy

 
Progress

 
Florida

 
Ohio

 
Indiana

Commodity Contracts
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Not Designated as Hedging Instruments
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Current
 
$
84

 
$
7

 
$
77

 
$
18

 
$
59

 
$

 
$
1

Noncurrent
 
23

 

 
23

 

 
17

 

 

Total Derivative Liabilities – Commodity Contracts
 
$
107

 
$
7

 
$
100

 
$
18

 
$
76

 
$

 
$
1

Interest Rate Contracts
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Designated as Hedging Instruments
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Current
 
$
9

 
$

 
$

 
$

 
$

 
$

 
$

Noncurrent
 
52

 

 

 

 

 

 

Not Designated as Hedging Instruments
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Current(a)
 
170

 

 

 

 

 
1

 

Noncurrent
 
90

 
82

 

 

 

 
7

 

Total Derivative Liabilities – Interest Rate Contracts
 
$
321

 
$
82

 
$

 
$

 
$

 
$
8

 
$

Total Derivative Liabilities
 
$
428


$
89


$
100


$
18


$
76


$
8


$
1

(a)
Duke Energy amount includes $168 million related to forward-starting interest rate swaps associated with the Piedmont acquisition.

61


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

Derivative Assets
 
December 31, 2015
 
 
 
 
Duke

 
 
 
Duke

 
Duke

 
Duke

 
Duke

 
 
Duke

 
Energy

 
Progress

 
Energy

 
Energy

 
Energy

 
Energy

(in millions)
 
Energy

 
Carolinas

 
Energy

 
Progress

 
Florida

 
Ohio

 
Indiana

Commodity Contracts
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Not Designated as Hedging Instruments
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Current
 
$
12

 
$

 
$
1

 
$

 
$
1

 
$
3

 
$
7

Noncurrent
 
4

 

 
4

 

 
4

 

 

Total Derivative Assets – Commodity Contracts
 
$
16

 
$

 
$
5

 
$

 
$
5

 
$
3

 
$
7

Interest Rate Contracts
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Designated as Hedging Instruments
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Noncurrent
 
$
4

 
$

 
$

 
$

 
$

 
$

 
$

Not Designated as Hedging Instruments
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Current
 
6

 

 
6

 
2

 
2

 

 

Total Derivative Assets – Interest Rate Contracts
 
$
10

 
$

 
$
6

 
$
2

 
$
2

 
$

 
$

Total Derivative Assets
 
$
26

 
$

 
$
11

 
$
2

 
$
7

 
$
3

 
$
7

Derivative Liabilities
 
December 31, 2015
 
 
 
 
Duke

 
 
 
Duke

 
Duke

 
Duke

 
Duke

 
 
Duke

 
Energy

 
Progress

 
Energy

 
Energy

 
Energy

 
Energy

(in millions)
 
Energy

 
Carolinas

 
Energy

 
Progress

 
Florida

 
Ohio

 
Indiana

Commodity Contracts
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Not Designated as Hedging Instruments
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Current
 
$
256

 
$
32

 
$
222

 
$
77

 
$
145

 
$

 
$

Noncurrent
 
100

 
8

 
92

 
16

 
71

 

 

Total Derivative Liabilities – Commodity Contracts
 
$
356

 
$
40

 
$
314

 
$
93

 
$
216

 
$

 
$

Interest Rate Contracts
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Designated as Hedging Instruments
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Current
 
$
11

 
$

 
$

 
$

 
$

 
$

 
$

Noncurrent
 
33

 

 

 

 

 

 

Not Designated as Hedging Instruments
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Current
 
4

 

 
3

 

 

 
1

 

Noncurrent
 
15

 
5

 
5

 
5

 

 
6

 

Total Derivative Liabilities – Interest Rate Contracts
 
$
63

 
$
5

 
$
8

 
$
5

 
$

 
$
7

 
$

Total Derivative Liabilities
 
$
419

 
$
45

 
$
322

 
$
98

 
$
216

 
$
7

 
$

OFFSETTING ASSETS AND LIABILITIES
The following tables present the line items on the Condensed Consolidated Balance Sheets where derivatives are reported. Substantially all of Duke Energy's outstanding derivative contracts are subject to enforceable master netting arrangements. The Gross amounts offset in the tables below show the effect of these netting arrangements on financial position, and include collateral posted to offset the net position. The amounts shown are calculated by counterparty. Accounts receivable or accounts payable may also be available to offset exposures in the event of bankruptcy. These amounts are not included in the tables below.

62


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

Derivative Assets
 
June 30, 2016
 
 
 
 
Duke

 
 
 
Duke

 
Duke

 
Duke

 
Duke

 
 
Duke

 
Energy

 
Progress

 
Energy

 
Energy

 
Energy

 
Energy

(in millions)
 
Energy

 
Carolinas

 
Energy

 
Progress

 
Florida

 
Ohio

 
Indiana

Current
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gross amounts recognized
 
$
67

 
$
8

 
$
23

 
$
9

 
$
14

 
$
5

 
$
31

Gross amounts offset
 
(15
)
 
(3
)
 
(13
)
 
(6
)
 
(7
)
 

 

Net amounts presented in Current Assets: Other
 
$
52

 
$
5

 
$
10

 
$
3

 
$
7

 
$
5

 
$
31

Noncurrent
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gross amounts recognized
 
$
41

 
$
10

 
$
31

 
$
16

 
$
15

 
$

 
$

Gross amounts offset
 
(5
)
 

 
(5
)
 

 
(4
)
 

 

Net amounts presented in Investments and Other Assets: Other
 
$
36

 
$
10

 
$
26

 
$
16

 
$
11

 
$

 
$

Derivative Liabilities
 
June 30, 2016
 
 
 
 
Duke

 
 
 
Duke

 
Duke

 
Duke

 
Duke

 
 
Duke

 
Energy

 
Progress

 
Energy

 
Energy

 
Energy

 
Energy

(in millions)
 
Energy

 
Carolinas

 
Energy

 
Progress

 
Florida

 
Ohio

 
Indiana

Current
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gross amounts recognized
 
$
263

 
$
7

 
$
77

 
$
18

 
$
59

 
$
1

 
$
1

Gross amounts offset
 
(15
)
 
(3
)
 
(13
)
 
(6
)
 
(7
)
 

 

Net amounts presented in Current Liabilities: Other
 
$
248

 
$
4

 
$
64

 
$
12

 
$
52

 
$
1

 
$
1

Noncurrent
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gross amounts recognized
 
$
165

 
$
82

 
$
23

 
$

 
$
17

 
$
7

 
$

Gross amounts offset
 
(5
)
 

 
(5
)
 

 
(4
)
 

 

Net amounts presented in Deferred Credits and Other Liabilities: Other
 
$
160

 
$
82

 
$
18

 
$

 
$
13

 
$
7

 
$

Derivative Assets
 
December 31, 2015
 
 
 
 
Duke

 
 
 
Duke

 
Duke

 
Duke

 
Duke

 
 
Duke

 
Energy

 
Progress

 
Energy

 
Energy

 
Energy

 
Energy

(in millions)
 
Energy

 
Carolinas

 
Energy

 
Progress

 
Florida

 
Ohio

 
Indiana

Current
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gross amounts recognized
 
$
18

 
$

 
$
7

 
$
2

 
$
3

 
$
3

 
$
7

Gross amounts offset
 
(3
)
 

 
(2
)
 

 
(2
)
 

 

Net amounts presented in Current Assets: Other
 
$
15

 
$

 
$
5

 
$
2

 
$
1

 
$
3

 
$
7

Noncurrent
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gross amounts recognized
 
$
8

 
$

 
$
4

 
$

 
$
4

 
$

 
$

Gross amounts offset
 
(4
)
 

 
(4
)
 

 
(4
)
 

 

Net amounts presented in Investments and Other Assets: Other
 
$
4

 
$

 
$

 
$

 
$

 
$

 
$

Derivative Liabilities
 
December 31, 2015
 
 
 
 
Duke

 
 
 
Duke

 
Duke

 
Duke

 
Duke

 
 
Duke

 
Energy

 
Progress

 
Energy

 
Energy

 
Energy

 
Energy

(in millions)
 
Energy

 
Carolinas

 
Energy

 
Progress

 
Florida

 
Ohio

 
Indiana

Current
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gross amounts recognized
 
$
271

 
$
32

 
$
225

 
$
77

 
$
145

 
$
1

 
$

Gross amounts offset
 
(22
)
 

 
(21
)
 
(1
)
 
(20
)
 

 

Net amounts presented in Current Liabilities: Other
 
$
249

 
$
32

 
$
204

 
$
76

 
$
125

 
$
1

 
$

Noncurrent
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gross amounts recognized
 
$
148

 
$
13

 
$
97

 
$
21

 
$
71

 
$
6

 
$

Gross amounts offset
 
(16
)
 

 
(15
)
 

 
(15
)
 

 

Net amounts presented in Deferred Credits and Other Liabilities: Other
 
$
132

 
$
13

 
$
82

 
$
21

 
$
56

 
$
6

 
$


63


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

OBJECTIVE CREDIT CONTINGENT FEATURES
Certain derivative contracts contain objective credit contingent features. These features include the requirement to post cash collateral or letters of credit if specific events occur, such as a credit rating downgrade below investment grade. The following tables show information with respect to derivative contracts that are in a net liability position and contain objective credit-risk-related payment provisions. Amounts for Duke Energy Ohio and Duke Energy Indiana were not material.
 
June 30, 2016
 
 
 
Duke

 
 
 
Duke

 
Duke

 
Duke

 
Energy

 
Progress

 
Energy

 
Energy

(in millions)
Energy

 
Carolinas

 
Energy

 
Progress

 
Florida

Aggregate fair value of derivatives in a net liability position
$
348

 
$
89

 
$
90

 
$
18

 
$
72

Fair value of collateral already posted

 

 

 

 

Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered
348

 
89

 
90

 
18

 
72

 
December 31, 2015
 
 
 
Duke

 
 
 
Duke

 
Duke

 
Duke

 
Energy

 
Progress

 
Energy

 
Energy

(in millions)
Energy

 
Carolinas

 
Energy

 
Progress

 
Florida

Aggregate fair value of derivatives in a net liability position
$
334

 
$
45

 
$
290

 
$
93

 
$
194

Fair value of collateral already posted
30

 

 
30

 

 
30

Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered
304

 
45

 
260

 
93

 
164

The Duke Energy Registrants have elected to offset cash collateral and fair values of derivatives. For amounts to be netted, the derivative must be executed with the same counterparty under the same master netting arrangement. Amounts disclosed below represent the receivables related to the right to reclaim cash collateral under master netting arrangements. All receivables presented below were offset against net derivative positions on the Condensed Consolidated Balance Sheets.
 
June 30, 2016
 
December 31, 2015
(in millions)
Receivables
 
Receivables
Duke Energy
$

 
$
30

Progress Energy

 
30

Duke Energy Florida

 
30

10. INVESTMENTS IN DEBT AND EQUITY SECURITIES
The Duke Energy Registrants classify their investments in debt and equity securities as available-for-sale.
Duke Energy’s available-for-sale securities are primarily comprised of investments held in (i) the nuclear decommissioning fund (NDTF) at Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida, (ii) grantor trusts at Duke Energy Progress, Duke Energy Florida and Duke Energy Indiana related to Other Post-Retirement Benefit Obligations (OPEB) plans and (iii) Bison.
Duke Energy classifies all other investments in debt and equity securities as long term, unless otherwise noted.
Investment Trusts
The investments within the NDTF investments and the Duke Energy Progress, Duke Energy Florida and Duke Energy Indiana grantor trusts (Investment Trusts) are managed by independent investment managers with discretion to buy, sell, and invest pursuant to the objectives set forth by the trust agreements. The Duke Energy Registrants have limited oversight of the day-to-day management of these investments. As a result, the ability to hold investments in unrealized loss positions is outside the control of the Duke Energy Registrants. Accordingly, all unrealized losses associated with debt and equity securities within the Investment Trusts are considered other-than-temporary impairments and are recognized immediately.
Investments within the Investment Trusts generally qualify for regulatory accounting, and accordingly realized and unrealized gains and losses are deferred as a regulatory asset or liability. However, certain investments held in Duke Energy Florida's NDTF, which were acquired in a settlement with Florida Municipal Joint Owners (FMJO), do not qualify for regulatory accounting. Except for other than temporary impairments of unrealized losses, unrealized gains and losses on these assets are included in other comprehensive income until realized. The other than temporary impairments of realized amounts and unrealized losses are included within Other income and expense, net on the Condensed Consolidated Statements of Operations. The value of these assets has not materially changed since the assets were acquired from FMJO. As a result, there is no material impact on earnings of the Duke Energy Registrants.

64


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

Other Available-for-Sale Securities
Unrealized gains and losses on all other available-for-sale securities are included in other comprehensive income until realized, unless it is determined the carrying value of an investment is other-than-temporarily impaired. The Duke Energy Registrants analyze all investment holdings each reporting period to determine whether a decline in fair value should be considered other-than-temporary. If an other than temporary impairment exists, the unrealized loss is included in earnings. There were no material credit losses as of June 30, 2016 and December 31, 2015.
DUKE ENERGY
The following table presents the estimated fair value of investments in available-for-sale securities.
 
June 30, 2016
 
December 31, 2015
 
Gross

 
Gross

 
 
 
Gross

 
Gross

 
 
 
Unrealized

 
Unrealized

 
Estimated

 
Unrealized

 
Unrealized

 
Estimated

 
Holding

 
Holding

 
Fair

 
Holding

 
Holding

 
Fair

(in millions)
Gains

 
Losses(b)

 
Value

 
Gains

 
Losses(b)

 
Value

NDTF
 
 
 
 
 
 
 
 
 
 
 
Cash and cash equivalents
$

 
$

 
$
189

 
$

 
$

 
$
179

Equity securities
1,869

 
78

 
3,834

 
1,823

 
58

 
3,590

Corporate debt securities
22

 
1

 
480

 
7

 
8

 
432

Municipal bonds
12

 
1

 
307

 
5

 
1

 
185

U.S. government bonds
38

 

 
1,038

 
11

 
5

 
1,254

Other debt securities
1

 
3

 
144

 

 
4

 
177

Total NDTF
$
1,942

 
$
83

 
$
5,992

 
$
1,846

 
$
76

 
$
5,817

Other Investments
 
 
 
 
 
 
 

 
 

 
 

Cash and cash equivalents
$

 
$

 
$
27

 
$

 
$

 
$
29

Equity securities
34

 
1

 
98

 
32

 
1

 
95

Corporate debt securities
2

 
1

 
97

 
1

 
3

 
92

Municipal bonds
6

 
1

 
80

 
3

 
1

 
74

U.S. government bonds
2

 

 
47

 

 

 
45

Other debt securities

 
1

 
57

 

 
2

 
62

Total Other Investments(a)
$
44

 
$
4

 
$
406

 
$
36

 
$
7

 
$
397

Total Investments
$
1,986

 
$
87

 
$
6,398

 
$
1,882

 
$
83

 
$
6,214

(a)    These amounts are recorded in Other within Investments and Other Assets on the Condensed Consolidated Balance Sheets.
(b)
Substantially all these amounts are considered other-than-temporary impairments on investments within Investment Trusts that have been recognized immediately as a regulatory asset.
The table below summarizes the maturity date for debt securities.
(in millions)
June 30, 2016

Due in one year or less
$
88

Due after one through five years
660

Due after five through 10 years
511

Due after 10 years
991

Total
$
2,250

Realized gains and losses, which were determined on a specific identification basis, from sales of available-for-sale securities were as follows.
 
Three Months Ended
 
Six Months Ended
 
June 30,
 
June 30,
(in millions)
2016

 
2015

 
2016

 
2015

Realized gains
$
64

 
$
28

 
$
118

 
$
130

Realized losses
42

 
17

 
92

 
31


65


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

DUKE ENERGY CAROLINAS
The following table presents the estimated fair value of investments in available-for-sale securities.
 
June 30, 2016
 
December 31, 2015
 
Gross

 
Gross

 
 
 
Gross

 
Gross

 
 
 
Unrealized

 
Unrealized

 
Estimated

 
Unrealized

 
Unrealized

 
Estimated

 
Holding

 
Holding

 
Fair

 
Holding

 
Holding

 
Fair

(in millions)
Gains

 
Losses(b)

 
Value

 
Gains

 
Losses(b)

 
Value

NDTF
 
 
 
 
 
 
 
 
 
 
 
Cash and cash equivalents
$

 
$

 
$
66

 
$

 
$

 
$
34

Equity securities
1,045

 
44

 
2,128

 
1,021

 
27

 
2,094

Corporate debt securities
13

 
1

 
309

 
3

 
5

 
292

Municipal bonds
2

 

 
42

 
1

 

 
33

U.S. government bonds
16

 

 
482

 
3

 
3

 
438

Other debt securities
1

 
3

 
136

 

 
4

 
147

Total NDTF
$
1,077

 
$
48


$
3,163

 
$
1,028

 
$
39

 
$
3,038

Other Investments
 
 
 
 
 
 
 
 
 
 
 
Other debt securities
$

 
$
1

 
$
3

 
$

 
$
1

 
$
3

Total Other Investments(a)
$

 
$
1

 
$
3

 
$

 
$
1

 
$
3

Total Investments
$
1,077

 
$
49

 
$
3,166

 
$
1,028

 
$
40

 
$
3,041

(a)
These amounts are recorded in Other within Investments and Other Assets on the Condensed Consolidated Balance Sheets.
(b)
Substantially all these amounts represent other-than-temporary impairments on investments within Investment Trusts that have been recognized immediately as a regulatory asset.
The table below summarizes the maturity date for debt securities.
(in millions)
June 30, 2016

Due in one year or less
$
6

Due after one through five years
198

Due after five through 10 years
235

Due after 10 years
533

Total
$
972

Realized gains and losses, which were determined on a specific identification basis, from sales of available-for-sale securities were as follows.
 
Three Months Ended
 
Six Months Ended
 
June 30,
 
June 30,
(in millions)
2016

 
2015

 
2016

 
2015

Realized gains
$
33

 
$
17

 
$
67

 
$
107

Realized losses
19

 
11

 
56

 
23


66


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

PROGRESS ENERGY
The following table presents the estimated fair value of investments in available-for-sale securities.
 
June 30, 2016
 
December 31, 2015
 
Gross

 
Gross

 
 
 
Gross

 
Gross

 
 
 
Unrealized

 
Unrealized

 
Estimated

 
Unrealized

 
Unrealized

 
Estimated

 
Holding

 
Holding

 
Fair

 
Holding

 
Holding

 
Fair

(in millions)
Gains

 
Losses(b)

 
Value

 
Gains

 
Losses(b)

 
Value

NDTF
 
 
 
 
 
 
 
 
 
 
 
Cash and cash equivalents
$

 
$

 
$
123

 
$

 
$

 
$
145

Equity securities
824

 
34

 
1,706

 
802

 
31

 
1,496

Corporate debt securities
9

 

 
171

 
4

 
3

 
140

Municipal bonds
10

 
1

 
265

 
4

 
1

 
152

U.S. government bonds
22

 

 
556

 
8

 
2

 
816

Other debt securities

 

 
8

 

 

 
30

Total NDTF
$
865

 
$
35

 
$
2,829

 
$
818

 
$
37

 
$
2,779

Other Investments
 
 
 
 
 
 
 
 
 
 
 
Cash and cash equivalents
$

 
$

 
$
21

 
$

 
$

 
$
18

Municipal bonds
4

 

 
47

 
3

 

 
45

Total Other Investments(a)
$
4

 
$

 
$
68

 
$
3

 
$

 
$
63

Total Investments
$
869

 
$
35

 
$
2,897

 
$
821

 
$
37

 
$
2,842

(a)    These amounts are recorded in Other within Investments and Other Assets on the Condensed Consolidated Balance Sheets.
(b)
Substantially all these amounts represent other-than-temporary impairments on investments within Investment Trusts that have been recognized immediately as a regulatory asset.
The table below summarizes the maturity date for debt securities.
(in millions)
June 30, 2016

Due in one year or less
$
65

Due after one through five years
375

Due after five through 10 years
200

Due after 10 years
407

Total
$
1,047

Realized gains and losses, which were determined on a specific identification basis, from sales of available-for-sale securities were as follows.
 
Three Months Ended
 
Six Months Ended
 
June 30,
 
June 30,
(in millions)
2016

 
2015

 
2016

 
2015

Realized gains
$
31

 
$
9

 
$
50

 
$
21

Realized losses
23

 
5

 
36

 
6


67


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

DUKE ENERGY PROGRESS
The following table presents the estimated fair value of investments in available-for-sale securities.
 
June 30, 2016
 
December 31, 2015
 
Gross

 
Gross

 
 
 
Gross

 
Gross

 
 
 
Unrealized

 
Unrealized

 
Estimated

 
Unrealized

 
Unrealized

 
Estimated

 
Holding

 
Holding

 
Fair

 
Holding

 
Holding

 
Fair

(in millions)
Gains

 
Losses(b)

 
Value

 
Gains

 
Losses(b)

 
Value

NDTF
 
 
 
 
 
 
 
 
 
 
 
Cash and cash equivalents
$

 
$

 
$
58

 
$

 
$

 
$
110

Equity securities
614

 
28

 
1,379

 
596

 
25

 
1,178

Corporate debt securities
7

 

 
118

 
3

 
2

 
96

Municipal bonds
10

 
1

 
265

 
4

 
1

 
150

U.S. government bonds
14

 

 
281

 
6

 
2

 
486

Other debt securities

 

 
5

 

 

 
18

Total NDTF
$
645

 
$
29

 
$
2,106

 
$
609

 
$
30

 
$
2,038

Other Investments
 
 
 
 
 
 
 

 
 

 
 

Cash and cash equivalents
$

 
$

 
$
1

 
$

 
$

 
$
1

Total Other Investments(a)
$

 
$

 
$
1

 
$

 
$

 
$
1

Total Investments
$
645

 
$
29

 
$
2,107

 
$
609

 
$
30

 
$
2,039

(a)    These amounts are recorded in Other within Investments and Other Assets on the Condensed Consolidated Balance Sheets.
(b)
Substantially all these amounts represent other-than-temporary impairments on investments within Investment Trusts that have been recognized immediately as a regulatory asset.
The table below summarizes the maturity date for debt securities.
(in millions)
June 30, 2016

Due in one year or less
$
14

Due after one through five years
191

Due after five through 10 years
154

Due after 10 years
310

Total
$
669

Realized gains and losses, which were determined on a specific identification basis, from sales of available-for-sale securities were as follows.
 
Three Months Ended
 
Six Months Ended
 
June 30,
 
June 30,
(in millions)
2016

 
2015

 
2016

 
2015

Realized gains
$
27

 
$
8

 
$
42

 
$
17

Realized losses
20

 
4

 
31

 
5


68


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

DUKE ENERGY FLORIDA
The following table presents the estimated fair value of investments in available-for-sale securities.
 
June 30, 2016
 
December 31, 2015
 
Gross

 
Gross

 
 
 
Gross

 
Gross

 
 
 
Unrealized

 
Unrealized

 
Estimated

 
Unrealized

 
Unrealized

 
Estimated

 
Holding

 
Holding

 
Fair

 
Holding

 
Holding

 
Fair

(in millions)
Gains

 
Losses(b)

 
Value

 
Gains

 
Losses(b)

 
Value

NDTF
 
 
 
 
 
 
 
 
 
 
 
Cash and cash equivalents
$

 
$

 
$
65

 
$

 
$

 
$
35

Equity securities
210

 
6

 
327

 
206

 
6

 
318

Corporate debt securities
2

 

 
53

 
1

 
1

 
44

Municipal bonds

 

 

 

 

 
2

U.S. government bonds
8

 

 
275

 
2

 

 
330

Other debt securities

 

 
3

 

 

 
12

Total NDTF
$
220

 
$
6

 
$
723

 
$
209

 
$
7

 
$
741

Other Investments
 
 
 
 
 
 
 

 
 

 
 

Cash and cash equivalents
$

 
$

 
$
4

 
$

 
$

 
$
6

Municipal bonds
4

 

 
47

 
3

 

 
45

Total Other Investments(a)
$
4

 
$

 
$
51

 
$
3

 
$

 
$
51

Total Investments
$
224

 
$
6

 
$
774

 
$
212

 
$
7

 
$
792

(a)    These amounts are recorded in Other within Investments and Other Assets on the Condensed Consolidated Balance Sheets.
(b)
Substantially all these amounts represent other-than-temporary impairments on investments within Investment Trusts that have been recognized immediately as a regulatory asset.
The table below summarizes the maturity date for debt securities.
(in millions)
June 30, 2016

Due in one year or less
$
51

Due after one through five years
184

Due after five through 10 years
46

Due after 10 years
97

Total
$
378

Realized gains and losses, which were determined on a specific identification basis, from sales of available-for-sale securities were as follows.
 
Three Months Ended
 
Six Months Ended
 
June 30,
 
June 30,
(in millions)
2016

 
2015

 
2016

 
2015

Realized gains
$
4

 
$
1

 
$
8

 
$
4

Realized losses
3

 
1

 
5

 
1


69


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

DUKE ENERGY INDIANA
The following table presents the estimated fair value of investments in available-for-sale securities.
 
June 30, 2016
 
December 31, 2015
 
Gross

 
Gross

 
 
 
Gross

 
Gross

 
 
 
Unrealized

 
Unrealized

 
Estimated

 
Unrealized

 
Unrealized

 
Estimated

 
Holding

 
Holding

 
Fair

 
Holding

 
Holding

 
Fair

(in millions)
Gains

 
Losses(b)

 
Value

 
Gains

 
Losses(b)

 
Value

Other Investments
 
 
 
 
 
 
 
 
 
 
 
Cash and cash equivalents
$

 
$

 
$

 
$

 
$

 
$
2

Equity securities
28

 

 
73

 
27

 

 
71

Corporate debt securities

 

 
2

 

 

 
2

Municipal bonds
1

 
1

 
29

 

 
1

 
26

Total Other Investments(a)
$
29

 
$
1


$
104

 
$
27

 
$
1

 
$
101

Total Investments
$
29

 
$
1

 
$
104

 
$
27

 
$
1

 
$
101

(a)    These amounts are recorded in Other within Investments and Other Assets on the Condensed Consolidated Balance Sheets.
(b)
Substantially all these amounts represent other-than-temporary impairments on investments within Investment Trusts that have been recognized immediately as a regulatory asset.
The table below summarizes the maturity date for debt securities.
(in millions)
June 30, 2016

Due in one year or less
$
2

Due after one through five years
16

Due after five through 10 years
8

Due after 10 years
5

Total
$
31

Realized gains and losses, which were determined on a specific identification basis, from sales of available-for-sale securities were insignificant for the three and six months ended June 30, 2016 and 2015.
11. FAIR VALUE MEASUREMENTS
Fair value is the exchange price to sell an asset or transfer a liability in an orderly transaction between market participants at the measurement date. The fair value definition focuses on an exit price versus the acquisition cost. Fair value measurements use market data or assumptions market participants would use in pricing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation technique. These inputs may be readily observable, corroborated by market data, or generally unobservable. Valuation techniques maximize the use of observable inputs and minimize use of unobservable inputs. A midmarket pricing convention (the midpoint price between bid and ask prices) is permitted for use as a practical expedient.
Fair value measurements are classified in three levels based on the fair value hierarchy:
Level 1 – Unadjusted quoted prices in active markets for identical assets or liabilities that the reporting entity can access at the measurement date. An active market is one in which transactions for an asset or liability occur with sufficient frequency and volume to provide ongoing pricing information.
Level 2 – A fair value measurement utilizing inputs other than quoted prices included in Level 1 that are observable, either directly or indirectly, for an asset or liability. Inputs include (i) quoted prices for similar assets or liabilities in active markets, (ii) quoted prices for identical or similar assets or liabilities in markets that are not active, (iii) and inputs other than quoted market prices that are observable for the asset or liability, such as interest rate curves and yield curves observable at commonly quoted intervals, volatilities and credit spreads. A Level 2 measurement cannot have more than an insignificant portion of its valuation based on unobservable inputs. Instruments in this category include non-exchange-traded derivatives, such as over-the-counter forwards, swaps and options; certain marketable debt securities; and financial instruments traded in less than active markets.
Level 3 – Any fair value measurement which includes unobservable inputs for more than an insignificant portion of the valuation. These inputs may be used with internally developed methodologies that result in management’s best estimate of fair value. Level 3 measurements may include longer-term instruments that extend into periods in which observable inputs are not available.
Not Categorized – Certain investments are not categorized within the Fair Value hierarchy. These investments are measured based on the fair value of the underlying investments but may not be readily redeemable at that fair value.
Fair value accounting guidance permits entities to elect to measure certain financial instruments that are not required to be accounted for at fair value, such as equity method investments or the company’s own debt, at fair value. The Duke Energy Registrants have not elected to record any of these items at fair value.

70


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

Transfers between levels represent assets or liabilities that were previously (i) categorized at a higher level for which the inputs to the estimate became less observable or (ii) classified at a lower level for which the inputs became more observable during the period. The Duke Energy Registrant’s policy is to recognize transfers between levels of the fair value hierarchy at the end of the period. There were no transfers between levels during the three and six months ended June 30, 2016 and 2015.
Valuation methods of the primary fair value measurements disclosed below are as follows.
Investments in equity securities
The majority of investments in equity securities are valued using Level 1 measurements. Investments in equity securities are typically valued at the closing price in the principal active market as of the last business day of the quarter. Principal active markets for equity prices include published exchanges such as Nasdaq Composite (NASDAQ) and New York Stock Exchange (NYSE). Foreign equity prices are translated from their trading currency using the currency exchange rate in effect at the close of the principal active market. There was no after-hours market activity that was required to be reflected in the reported fair value measurements.
Investments in debt securities
Most investments in debt securities are valued using Level 2 measurements because the valuations use interest rate curves and credit spreads applied to the terms of the debt instrument (maturity and coupon interest rate) and consider the counterparty credit rating. If the market for a particular fixed income security is relatively inactive or illiquid, the measurement is Level 3.
Commodity derivatives
Commodity derivatives with clearinghouses are classified as Level 1. Other commodity derivatives are primarily valued using internally developed discounted cash flow models which incorporate forward price, adjustments for liquidity (bid-ask spread) and credit or non-performance risk (after reflecting credit enhancements such as collateral), and are discounted to present value. Pricing inputs are derived from published exchange transaction prices and other observable data sources. In the absence of an active market, the last available price may be used. If forward price curves are not observable for the full term of the contract and the unobservable period had more than an insignificant impact on the valuation, the commodity derivative is classified as Level 3. In isolation, increases (decreases) in natural gas forward prices result in favorable (unfavorable) fair value adjustments for natural gas purchase contracts; and increases (decreases) in electricity forward prices result in unfavorable (favorable) fair value adjustments for electricity sales contracts. Duke Energy regularly evaluates and validates pricing inputs used to estimate the fair value of natural gas commodity contracts by a market participant price verification procedure. This procedure provides a comparison of internal forward commodity curves to market participant generated curves.
Interest rate derivatives
Most over-the-counter interest rate contract derivatives are valued using financial models which utilize observable inputs for similar instruments and are classified as Level 2. Inputs include forward interest rate curves, notional amounts, interest rates and credit quality of the counterparties.
DUKE ENERGY
The following tables provide recorded balances for assets and liabilities measured at fair value on a recurring basis on the Condensed Consolidated Balance Sheets. Derivative amounts in the table below exclude cash collateral which is disclosed in Note 9. See Note 10 for additional information related to investments by major security type.
 
June 30, 2016
(in millions)
Total Fair Value

Level 1

Level 2

Level 3

Not categorized

Nuclear decommissioning trust fund equity securities
$
3,834

$
3,666

$
1

$

$
167

Nuclear decommissioning trust fund debt securities
2,158

744

1,414



Other available-for-sale equity securities
98

98




Other available-for-sale debt securities
308

74

230

4


Derivative assets
108

2

72

34


Total assets
6,506

4,584

1,717

38

167

Derivative liabilities
(428
)
(1
)
(427
)


Net assets
$
6,078

$
4,583

$
1,290

$
38

$
167


71


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

 
December 31, 2015
(in millions)
Total Fair Value

Level 1

Level 2

Level 3

Not categorized

Nuclear decommissioning trust fund equity securities
$
3,590

$
3,418

$

$

$
172

Nuclear decommissioning trust fund debt securities
2,227

672

1,555



Other available-for-sale equity securities
95

95




Other available-for-sale debt securities
302

75

222

5


Derivative assets
26


16

10


Total assets
6,240

4,260

1,793

15

172

Derivative liabilities
(419
)

(419
)


Net assets
$
5,821

$
4,260

$
1,374

$
15

$
172

The following tables provide reconciliations of beginning and ending balances of assets and liabilities measured at fair value using Level 3 measurements. Amounts included in earnings for derivatives are primarily included in Operating Revenues. There was no change to the Level 3 balance during the three months ended June 30, 2015.
 
Three Months Ended June 30, 2016
(in millions)
Investments

 
Derivatives (net)

 
Total

Balance at beginning of period
$
4

 
$
2

 
$
6

Purchases, sales, issuances and settlements:
 
 
 
 


Purchases

 
34

 
34

Settlements

 
(6
)
 
(6
)
Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities

 
4

 
4

Balance at end of period
$
4

 
$
34

 
$
38

 
 
Six Months Ended June 30, 2016
(in millions)
Investments

 
Derivatives (net)

 
Total

Balance at beginning of period
$
5

 
$
10

 
$
15

Purchases, sales, issuances and settlements:
 
 
 
 
 
Purchases

 
34

 
34

Sales
(1
)
 

 
(1
)
Settlements

 
(13
)
 
(13
)
Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities

 
3

 
3

Balance at end of period
$
4

 
$
34

 
$
38

 
Six Months Ended June 30, 2015
(in millions)
Investments

 
Derivatives (net)

 
Total

Balance at beginning of period
$
5

 
$
(1
)
 
$
4

Total pretax realized or unrealized gains included in earnings

 
18

 
18

Purchases, sales, issuances and settlements:
 
 
 
 
 
Purchases

 
24

 
24

Settlements

 
(22
)
 
(22
)
Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities

 
4

 
4

Balance at end of period
$
5

 
$
23

 
$
28


72


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

DUKE ENERGY CAROLINAS
The following tables provide recorded balances for assets and liabilities measured at fair value on a recurring basis on the Condensed Consolidated Balance Sheets. Derivative amounts in the table below exclude cash collateral, which is disclosed in Note 9. See Note 10 for additional information related to investments by major security type.
 
June 30, 2016
(in millions)
Total Fair Value

Level 1

Level 2

Level 3

Not categorized

Nuclear decommissioning trust fund equity securities
$
2,128

$
1,960

$
1

$

$
167

Nuclear decommissioning trust fund debt securities
1,035

245

790



Other available-for-sale debt securities
3



3


Derivative assets
18


18



Total assets
3,184

2,205

809

3

167

Derivative liabilities
(89
)

(89
)


Net assets
$
3,095

$
2,205

$
720

$
3

$
167

 
December 31, 2015
(in millions)
Total Fair Value

Level 1

Level 2

Level 3

Not categorized

Nuclear decommissioning trust fund equity securities
$
2,094

$
1,922

$

$

$
172

Nuclear decommissioning trust fund debt securities
944

246

698



Other available-for-sale debt securities
3



3


Total assets
3,041

2,168

698

3

172

Derivative liabilities
(45
)

(45
)


Net assets
$
2,996

$
2,168

$
653

$
3

$
172

There was no change to the Level 3 balance during the three and six months ended June 30, 2016 and June 30, 2015.
 
 
PROGRESS ENERGY
The following tables provide recorded balances for assets and liabilities measured at fair value on a recurring basis on the Condensed Consolidated Balance Sheets. Derivative amounts in the table below exclude cash collateral, which is disclosed in Note 9. See Note 10 for additional information related to investments by major security type.
 
June 30, 2016
(in millions)
Total Fair Value

Level 1

Level 2

Nuclear decommissioning trust fund equity securities
$
1,706

$
1,706

$

Nuclear decommissioning trust fund debt securities
1,123

499

624

Other available-for-sale debt securities
68

21

47

Derivative assets
54


54

Total assets
2,951

2,226

725

Derivative liabilities
(100
)

(100
)
Net assets
$
2,851

$
2,226

$
625

 
December 31, 2015
(in millions)
Total Fair Value

Level 1

Level 2

Nuclear decommissioning trust fund equity securities
$
1,496

$
1,496

$

Nuclear decommissioning trust fund debt securities
1,283

426

857

Other available-for-sale debt securities
63

18

45

Derivative assets
11


11

Total assets
2,853

1,940

913

Derivative liabilities
(322
)

(322
)
Net assets
$
2,531

$
1,940

$
591


73


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

DUKE ENERGY PROGRESS
The following tables provide recorded balances for assets and liabilities measured at fair value on a recurring basis on the Condensed Consolidated Balance Sheets. Derivative amounts in the table below exclude cash collateral which is disclosed in Note 9. See Note 10 for additional information related to investments by major security type.
 
June 30, 2016
(in millions)
Total Fair Value

Level 1

Level 2

Nuclear decommissioning trust fund equity securities
$
1,379

$
1,379

$

Nuclear decommissioning trust fund debt securities and other
727

228

499

Other available-for-sale debt securities and other
1

1


Derivative assets
25


25

Total assets
2,132

1,608

524

Derivative liabilities
(18
)

(18
)
Net assets
$
2,114

$
1,608

$
506

 
December 31, 2015
(in millions)
Total Fair Value

Level 1

Level 2

Nuclear decommissioning trust fund equity securities
$
1,178

$
1,178

$

Nuclear decommissioning trust fund debt securities and other
860

141

719

Other available-for-sale debt securities and other
1

1


Derivative assets
2


2

Total assets
2,041

1,320

721

Derivative liabilities
(98
)

(98
)
Net assets
$
1,943

$
1,320

$
623

DUKE ENERGY FLORIDA
The following tables provide recorded balances for assets and liabilities measured at fair value on a recurring basis on the Condensed Consolidated Balance Sheets. Derivative amounts in the table below exclude cash collateral which is disclosed in Note 9. See Note 10 for additional information related to investments by major security type.
 
June 30, 2016
(in millions)
Total Fair Value

Level 1

Level 2

Nuclear decommissioning trust fund equity securities
$
327

$
327

$

Nuclear decommissioning trust fund debt securities and other
396

271

125

Other available-for-sale debt securities and other
51

4

47

Derivative assets
29


29

Total assets
803

602

201

Derivative liabilities
(76
)

(76
)
Net assets
$
727

$
602

$
125

 
December 31, 2015
(in millions)
Total Fair Value

Level 1

Level 2

Nuclear decommissioning trust fund equity securities
$
318

$
318

$

Nuclear decommissioning trust fund debt securities and other
423

285

138

Other available-for-sale debt securities and other
51

6

45

Derivative assets
7


7

Total assets
799

609

190

Derivative liabilities
(216
)

(216
)
Net assets (liabilities)
$
583

$
609

$
(26
)

74


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

DUKE ENERGY OHIO
The following tables provide recorded balances for assets and liabilities measured at fair value on a recurring basis on the Condensed Consolidated Balance Sheets. Derivative amounts in the table below exclude cash collateral, which are disclosed in Note 9.
 
June 30, 2016
(in millions)
Total Fair Value

Level 1

Level 2

Level 3

Derivative assets
$
5

$

$

$
5

Derivative liabilities
(8
)

(8
)

Net (liabilities) assets
$
(3
)
$

$
(8
)
$
5

 
December 31, 2015
(in millions)
Total Fair Value

Level 1

Level 2

Level 3

Derivative assets
$
3

$

$

$
3

Derivative liabilities
(7
)

(7
)

Net (liabilities) assets
$
(4
)
$

$
(7
)
$
3

The following table provides a reconciliation of beginning and ending balances of assets and liabilities measured at fair value using Level 3 measurements.
 
Derivatives (net)
 
Three Months Ended June 30,
(in millions)
2016

 
2015

Balance at beginning of period
$

 
$
7

Total pretax realized or unrealized gains included in earnings

 
(4
)
Purchases, sales, issuances and settlements:
 
 
 
Purchases
5

 

Sales

 
5

Settlements

 
(3
)
Balance at end of period
$
5

 
$
5

 
Derivatives (net)
 
Six Months Ended June 30,
(in millions)
2016

 
2015

Balance at beginning of period
$
3

 
$
(18
)
Total pretax realized or unrealized gains included in earnings

 
21

Purchases, sales, issuances and settlements:
 
 
 
Purchases
5

 

Sales

 
5

Settlements
(2
)
 
(3
)
Total losses included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities
(1
)
 

Balance at end of period
$
5

 
$
5


75


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

DUKE ENERGY INDIANA
The following tables provide recorded balances for assets and liabilities measured at fair value on a recurring basis on the Condensed Consolidated Balance Sheets. Derivative amounts in the table below exclude cash collateral, which is disclosed in Note 9. See Note 10 for additional information related to investments by major security type.
 
June 30, 2016
(in millions)
Total Fair Value

Level 1

Level 2

Level 3

Other available-for-sale equity securities
$
73

$
73

$

$

Other available-for-sale debt securities and other
31


31


Derivative assets
31

2


29

Total assets
135

75

31

29

Derivative liabilities
(1
)
(1
)


Net assets
$
134

$
74

$
31

$
29

 
December 31, 2015
(in millions)
Total Fair Value

Level 1

Level 2

Level 3

Other available-for-sale equity securities
$
71

$
71

$

$

Other available-for-sale debt securities and other
30

2

28


Derivative assets
7



7

Net assets
$
108

$
73

$
28

$
7

The following table provides a reconciliation of beginning and ending balances of assets and liabilities measured at fair value using Level 3 measurements.
 
Derivatives (net)
 
Three Months Ended June 30,
(in millions)
2016

 
2015

Balance at beginning of period
$
2

 
$
3

Purchases, sales, issuances and settlements:

 
 
Purchases
29

 
18

Settlements
(6
)
 
(10
)
Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities
4

 
6

Balance at end of period
$
29

 
$
17

 
Derivatives (net)
 
Six Months Ended June 30,
(in millions)
2016

 
2015

Balance at beginning of period
$
7

 
$
14

Purchases, sales, issuances and settlements:
 
 
 
Purchases
29

 
18

Settlements
(11
)
 
(19
)
Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities
4

 
4

Balance at end of period
$
29

 
$
17


76


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

QUANTITATIVE INFORMATION ABOUT UNOBSERVABLE INPUTS
The following table includes quantitative information about the Duke Energy Registrants' derivatives classified as Level 3. As of June 30, 2016 and December 31, 2015, all Level 3 derivatives were financial transmission rights (FTRs).
 
June 30, 2016
 
Fair Value of FTRs
 
 
 
 
 
 
(in millions)
Valuation Technique
Unobservable Input
Range
Duke Energy
$
34

RTO auction pricing
FTR price – per Megawatt-Hour (MWh)
$
(1.64
)
-
$
8.64

Duke Energy Ohio
5

RTO auction pricing
FTR price – per MWh
0.36

-
2.47

Duke Energy Indiana
29

RTO auction pricing
FTR price – per MWh
(1.64
)
-
8.64

 
December 31, 2015
 
Fair Value of FTRs
 
 
 
 
 
 
(in millions)
Valuation Technique
Unobservable Input
Range
Duke Energy
$
10

RTO auction pricing
FTR price – per MWh
$
(0.74
)
-
$
7.29

Duke Energy Ohio
3

RTO auction pricing
FTR price – per MWh
0.67

-
2.53

Duke Energy Indiana
7

RTO auction pricing
FTR price – per MWh
(0.74
)
-
7.29

OTHER FAIR VALUE DISCLOSURES
The fair value and book value of long-term debt, including current maturities, is summarized in the following table. Estimates determined are not necessarily indicative of amounts that could have been settled in current markets. Fair value of long-term debt uses Level 2 measurements.
 
June 30, 2016
 
December 31, 2015
(in millions)
Book Value

 
Fair Value

 
Book Value

 
Fair Value

Duke Energy
$
42,273

 
$
47,953

 
$
39,569

 
$
42,537

Duke Energy Carolinas
9,360

 
10,874

 
8,367

 
9,156

Progress Energy
15,486

 
16,715

 
14,464

 
15,856

Duke Energy Progress
6,565

 
7,344

 
6,518

 
6,757

Duke Energy Florida
5,540

 
5,226

 
4,266

 
4,908

Duke Energy Ohio
1,887

 
2,134

 
1,598

 
1,724

Duke Energy Indiana
3,937

 
4,717

 
3,768

 
4,219

At both June 30, 2016 and December 31, 2015, fair value of cash and cash equivalents, accounts and notes receivable, accounts payable, notes payable and commercial paper, and non-recourse notes payable of VIEs are not materially different from their carrying amounts because of the short-term nature of these instruments and/or because the stated rates approximate market rates.
12. VARIABLE INTEREST ENTITIES
A VIE is an entity that is evaluated for consolidation using more than a simple analysis of voting control. The analysis to determine whether an entity is a VIE considers contracts with an entity, credit support for an entity, the adequacy of the equity investment of an entity and the relationship of voting power to the amount of equity invested in an entity. This analysis is performed either upon the creation of a legal entity or upon the occurrence of an event requiring reevaluation, such as a significant change in an entity’s assets or activities. A qualitative analysis of control determines the party that consolidates a VIE. This assessment is based on (i) what party has the power to direct the activities of the VIE that most significantly impact its economic performance and (ii) what party has rights to receive benefits or is obligated to absorb losses that could potentially be significant to the VIE. The analysis of the party that consolidates a VIE is a continual reassessment.
CONSOLIDATED VIEs
The obligations of the consolidated VIEs discussed in the following paragraphs are nonrecourse to the Duke Energy registrants. The registrants have no requirement to provide liquidity to, purchase assets of or guarantee performance of these VIEs unless noted in the following paragraphs.
No financial support was provided to any of the consolidated VIEs during the six months ended June 30, 2016 and the year ended December 31, 2015, or is expected to be provided in the future, that was not previously contractually required.
Receivables Financing – DERF / DEPR / DEFR
Duke Energy Receivables Finance Company, LLC (DERF), Duke Energy Progress Receivables, LLC (DEPR) and Duke Energy Florida Receivables, LLC (DEFR) are bankruptcy remote, special purpose subsidiaries of Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida, respectively. DERF, DEPR and DEFR are wholly owned limited liability companies with separate legal existence from their parent companies, and their assets are not generally available to creditors of their parent companies. On a revolving basis, DERF, DEPR and DEFR buy certain accounts receivable arising from the sale of electricity and related services from their parent companies.

77


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

DERF, DEPR and DEFR borrow amounts under credit facilities to buy these receivables. Borrowing availability from the credit facilities is limited to the amount of qualified receivables purchased. The sole source of funds to satisfy the related debt obligations is cash collections from the receivables. Amounts borrowed under the credit facilities are reflected on the Condensed Consolidated Balance Sheets as Long-Term Debt.
The most significant activity that impacts the economic performance of DERF, DEPR and DEFR are the decisions made to manage delinquent receivables. Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida consolidate DERF, DEPR and DEFR, respectively, as they make those decisions.
Receivables Financing – CRC
CRC is a bankruptcy remote, special purpose entity indirectly owned by Duke Energy. On a revolving basis, CRC buys certain accounts receivable arising from the sale of electricity and related services from Duke Energy Ohio and Duke Energy Indiana. CRC borrows amounts under a credit facility to buy the receivables from Duke Energy Ohio and Duke Energy Indiana. Borrowing availability from the credit facility is limited to the amount of qualified receivables sold to CRC. The sole source of funds to satisfy the related debt obligation is cash collections from the receivables. Amounts borrowed under the credit facility are reflected on Duke Energy's Condensed Consolidated Balance Sheets as Long-Term Debt.
The proceeds Duke Energy Ohio and Duke Energy Indiana receive from the sale of receivables to CRC are typically 75 percent cash and 25 percent in the form of a subordinated note from CRC. The subordinated note is a retained interest in the receivables sold. Depending on collection experience, additional equity infusions to CRC may be required by Duke Energy to maintain a minimum equity balance of $3 million.
CRC is considered a VIE because (i) equity capitalization is insufficient to support its operations, (ii) power to direct the activities that most significantly impact the economic performance of the entity are not performed by the equity holder, and (iii) deficiencies in net worth of CRC are funded by Duke Energy. The most significant activities that impact the economic performance of CRC are decisions made to manage delinquent receivables. Duke Energy consolidates CRC as it makes these decisions. Neither Duke Energy Ohio nor Duke Energy Indiana consolidate CRC.
Receivables Financing – Credit Facilities
The following table summarizes the amounts and expiration dates of the credit facilities described above. Amounts borrowed under the credit facilities are reflected on the Condensed Consolidated Balance Sheets as Long-Term Debt.
 
Duke Energy
 
 
 
Duke Energy

 
Duke Energy

 
Duke Energy

 
 
 
Carolinas

 
Progress

 
Florida

 
CRC

 
DERF

 
DEPR

 
DEFR

Expiration date
December 2018

 
December 2018

 
February 2019

 
April 2019

Credit facility amount (in millions)
$
325

 
$
425

 
$
300

 
$
225

Amounts borrowed at June 30, 2016
325

 
425

 
300

 
225

Amounts borrowed at December 31, 2015
325

 
425

 
254

 
225

Nuclear Asset-Recovery Bonds – DEFPF
DEFPF is a bankruptcy remote, wholly owned special purpose subsidiary of Duke Energy Florida. DEFPF was formed in 2016 for the sole purpose of issuing nuclear asset-recovery bonds to finance Duke Energy Florida's unrecovered regulatory asset related to Crystal River Unit 3.
In June 2016, DEFPF issued $1,294 million of senior secured bonds and used the proceeds to acquire nuclear asset-recovery property from Duke Energy Florida. The nuclear asset-recovery property acquired includes the right to impose, bill, collect and adjust a non-bypassable nuclear asset-recovery charge from all Duke Energy Florida retail customers until the bonds are paid in full and all financing costs have been recovered. The nuclear asset-recovery bonds are secured by the nuclear asset-recovery property, and cash collections from the nuclear asset-recovery charges are the sole source of funds to satisfy the debt obligation. The bondholders have no recourse to Duke Energy Florida. For additional information see Notes 4 and 6.
DEFPF is considered a VIE primarily because the equity capitalization is insufficient to support its operations. Duke Energy Florida has the power to direct the significant activities of the VIE as described above, and therefore Duke Energy Florida is considered the primary beneficiary and consolidates DEFPF.
The following table summarizes the impact of DEFPF on Duke Energy Florida's Condensed Consolidated Balance Sheets.
(in millions)
June 30, 2016

Regulatory Assets: Current
$
34

Current Assets: Other
7

Regulatory Assets and Deferred Debits: Regulatory assets
1,194

Current maturities of long-term debt
35

Long-Term Debt
1,243


78


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

Renewables
Certain Duke Energy renewable energy facilities are VIEs due to long-term fixed-price power purchase agreements. These fixed-price agreements effectively transfer commodity price risk to the buyer of the power. Certain other Duke Energy renewable energy facilities are VIEs due to Duke Energy issuing guarantees for debt service and operations and maintenance reserves in support of debt financings. For certain VIEs, assets are restricted and cannot be pledged as collateral or sold to third parties without prior approval of debt holders. The activities that most significantly impact the economic performance of these renewable energy facilities were decisions associated with siting, negotiating purchase power agreements, engineering, procurement and construction, and decisions associated with ongoing operations and maintenance-related activities. Duke Energy consolidates the entities as it is responsible for all of these decisions.
The table below presents material balances reported on Duke Energy's Condensed Consolidated Balance Sheets related to renewables VIEs.
(in millions)
June 30, 2016

December 31, 2015

Current Assets: Other
$
223

$
138

Property, plant and equipment, cost
2,578

2,015

Accumulated depreciation and amortization
(376
)
(321
)
Current maturities of long-term debt
154

108

Long-Term Debt
866

968

Deferred Credits and Other Liabilities: Deferred income taxes
31

289

Deferred Credits and Other Liabilities: Other
277

33

NON-CONSOLIDATED VIEs
The following tables summarize the impact of non-consolidated VIEs on the Condensed Consolidated Balance Sheets.
 
June 30, 2016
 
Duke Energy
 
Duke

 
Duke

 
 
 
 
 
 
 
Energy

 
Energy

(in millions)
Renewables

 
Other

 
Total

 
Ohio

 
Indiana

Receivables from affiliated companies
$

 
$

 
$

 
$
39

 
$
58

Investments in equity method unconsolidated affiliates
222

 
252

 
474

 

 

Total assets
$
222

 
$
252

 
$
474

 
$
39

 
$
58

Other current liabilities

 
3

 
3

 

 

Deferred credits and other liabilities

 
13

 
13

 

 

Total liabilities
$

 
$
16

 
$
16

 
$

 
$

Net assets
$
222

 
$
236

 
$
458

 
$
39

 
$
58

 
December 31, 2015
 
Duke Energy
 
Duke

 
Duke

 
 
 
 
 
 
 
Energy

 
Energy

(in millions)
Renewables

 
Other

 
Total

 
Ohio

 
Indiana

Receivables from affiliated companies
$

 
$

 
$

 
$
47

 
$
60

Investments in equity method unconsolidated affiliates
235

 
152

 
387

 

 

Total assets
$
235

 
$
152

 
$
387

 
$
47

 
$
60

Other current liabilities

 
3

 
3

 

 

Deferred credits and other liabilities

 
14

 
14

 

 

Total liabilities
$

 
$
17

 
$
17

 
$

 
$

Net assets
$
235

 
$
135

 
$
370

 
$
47

 
$
60

The Duke Energy Registrants are not aware of any situations where the maximum exposure to loss significantly exceeds the carrying values shown above except for the power purchase agreement with Ohio Valley Electric Corporation (OVEC), which is discussed below, and various guarantees, reflected in the table above as Deferred credits and other liabilities. For more information on various guarantees, refer to Note 5.
Renewables
Duke Energy has investments in various renewable energy project entities. Some of these entities are VIEs due to long-term fixed-price power purchase agreements. These fixed-price agreements effectively transfer commodity price risk to the buyer of the power. Duke Energy does not consolidate these VIEs because power to direct and control key activities is shared jointly by Duke Energy and other owners.

79


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

Other
Duke Energy holds a 50 percent equity interest in Duke-American Transmission Company, LLC (DATC). DATC is considered a VIE due to insufficient equity at risk to permit DATC to finance its own activities without additional subordinated financial support. The activities that most significantly impact DATC’s economic performance are the decisions related to investing in existing and development of new transmission facilities. The power to direct these activities is jointly and equally shared by Duke Energy and the other joint venture partner, and therefore Duke Energy does not consolidate DATC.
Duke Energy has a 40 percent equity interest and a 7.5 percent equity interest in ACP and Sabal Trail Transmission, LLC (Sabal Trail), respectively. These entities are considered VIEs as their equity is not sufficient to permit the entities to finance their activities without additional subordinated financial support. The activity that most significantly impacts the economic performance of both ACP and Sabal Trail is construction. Duke Energy does not control these activities and therefore does not consolidate ACP or Sabal Trail.
OVEC
Duke Energy Ohio’s 9 percent ownership interest in OVEC is considered a non-consolidated VIE. Through its ownership interest in OVEC, Duke Energy Ohio has a contractual arrangement to buy power from OVEC’s power plants through June 2040. Proceeds from the sale of power by OVEC to its power purchase agreement counterparties are designed to be sufficient to meet its operating expenses, fixed costs, debt amortization and interest expense, as well as earn a return on equity. Accordingly, the value of this contract is subject to variability due to fluctuations in power prices and changes in OVEC’s costs of business, including costs associated with its 2,256 MW of coal-fired generation capacity. Proposed environmental rulemaking could increase the costs of OVEC, which would be passed through to Duke Energy Ohio.
CRC
See discussion under Consolidated VIEs for additional information related to CRC.
Amounts included in Receivables from affiliated companies in the above table for Duke Energy Ohio and Duke Energy Indiana reflect their retained interest in receivables sold to CRC. These subordinated notes held by Duke Energy Ohio and Duke Energy Indiana are stated at fair value. Carrying values of retained interests are determined by allocating carrying value of the receivables between assets sold and interests retained based on relative fair value. The allocated bases of the subordinated notes are not materially different than their face value because (i) the receivables generally turn over in less than two months, (ii) credit losses are reasonably predictable due to the broad customer base and lack of significant concentration, and (iii) the equity in CRC is subordinate to all retained interests and thus would absorb losses first. The hypothetical effect on fair value of the retained interests assuming both a 10 percent and a 20 percent unfavorable variation in credit losses or discount rates is not material due to the short turnover of receivables and historically low credit loss history. Interest accrues to Duke Energy Ohio and Duke Energy Indiana on the retained interests using the acceptable yield method. This method generally approximates the stated rate on the notes since the allocated basis and the face value are nearly equivalent. An impairment charge is recorded against the carrying value of both retained interests and purchased beneficial interest whenever it is determined that an other-than-temporary impairment has occurred.
Key assumptions used in estimating fair value are detailed in the following table.
 
Duke Energy Ohio
 
Duke Energy Indiana
 
2016

 
2015

 
2016

 
2015

Anticipated credit loss ratio
0.5
%
 
0.6
%
 
0.3
%
 
0.3
%
Discount rate
1.4
%
 
1.2
%
 
1.4
%
 
1.2
%
Receivable turnover rate
13.2
%
 
12.9
%
 
10.6
%
 
10.6
%
The following table shows the gross and net receivables sold.
 
Duke Energy Ohio
 
Duke Energy Indiana
(in millions)
June 30, 2016

 
December 31, 2015

 
June 30, 2016

 
December 31, 2015

Receivables sold
$
208

 
$
233

 
$
279

 
$
260

Less: Retained interests
39

 
47

 
58

 
60

Net receivables sold
$
169

 
$
186

 
$
221

 
$
200


80


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

The following table shows sales and cash flows related to receivables sold.
 
Duke Energy Ohio
 
Duke Energy Indiana
 
Three Months Ended
 
Six Months Ended
 
Three Months Ended
 
Six Months Ended
 
June 30,
 
June 30,
 
June 30,
 
June 30,
(in millions)
2016

 
2015

 
2016

 
2015

 
2016

 
2015

 
2016

 
2015

Sales
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Receivables sold
$
429

 
$
425

 
$
961

 
$
1,069

 
$
623

 
$
637

 
$
1,258

 
$
1,353

Loss recognized on sale
2

 
2

 
5

 
5

 
2

 
2

 
5

 
5

Cash flows
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Cash proceeds from receivables sold
427

 
467

 
964

 
1,107

 
612

 
660

 
1,255

 
1,382

Collection fees received

 
1

 

 
1

 
1

 
1

 
1

 
1

Return received on retained interests

 
1

 
1

 
2

 
1

 
1

 
2

 
3

Cash flows from sales of receivables are reflected within Operating Activities on Duke Energy Ohio’s and Duke Energy Indiana’s Condensed Consolidated Statements of Cash Flows.
Collection fees received in connection with servicing transferred accounts receivable are included in Operation, maintenance and other on Duke Energy Ohio’s and Duke Energy Indiana’s Condensed Consolidated Statements of Operations and Comprehensive Income. The loss recognized on sales of receivables is calculated monthly by multiplying receivables sold during the month by the required discount. The required discount is derived monthly utilizing a three-year weighted average formula that considers charge-off history, late charge history and turnover history on the sold receivables, as well as a component for the time value of money. The discount rate, or component for the time value of money, is the prior month-end LIBOR plus a fixed rate of 1.00 percent.
13. COMMON STOCK
Basic Earnings Per Share (EPS) is computed by dividing net income attributable to Duke Energy common stockholders, adjusted for distributed and undistributed earnings allocated to participating securities, by the weighted average number of common stock outstanding during the period. Diluted EPS is computed by dividing net income attributable to Duke Energy common stockholders, as adjusted for distributed and undistributed earnings allocated to participating securities, by the diluted weighted average number of common stock outstanding during the period. Diluted EPS reflects the potential dilution that could occur if securities or other agreements to issue common stock, such as stock options and the Equity Forwards, were exercised or settled. Duke Energy’s participating securities are restricted stock units that are entitled to dividends declared on Duke Energy common stock during the restricted stock unit’s vesting periods.
The following table presents Duke Energy’s basic and diluted EPS calculations and reconciles the weighted average number of common stock outstanding to the diluted weighted average number of common shares outstanding.
 
Three Months Ended June 30,
 
Six Months Ended June 30,
(in millions, except per-share amounts)
2016

 
2015

 
2016
 
2015
Income from continuing operations attributable to Duke Energy common stockholders excluding impact of participating securities
$
508

 
$
600

 
$
1,199

 
$
1,372

Weighted average shares outstanding – basic
689

 
692

 
689

 
700

Equity Forwards
1

 

 

 

Weighted average shares outstanding – diluted
690
 
692
 
689
 
700
Earnings per share from continuing operations attributable to Duke Energy common stockholders
 
 
 
 
 
 
 
Basic
$
0.74

 
$
0.87

 
$
1.74

 
$
1.96

Diluted
$
0.74

 
$
0.87

 
$
1.74

 
$
1.96

Potentially dilutive items excluded from the calculation(a)
2

 
2

 
2
 
2
Dividends declared per common share
$
0.825

 
$
0.795

 
$
1.65

 
$
1.59

(a)
Performance stock awards were not included in the dilutive securities calculation because the performance measures related to the awards had not been met.
Equity Forwards
In March 2016, Duke Energy marketed an equity offering of 10.6 million shares of common stock. In lieu of issuing equity at the time of the offering, Duke Energy entered into Equity Forwards with Barclays. No amounts have or will be recorded in Duke Energy’s Condensed Consolidated Financial Statements with respect to the equity offering until settlements of the Equity Forwards occur. The Equity Forwards require Duke Energy to, at its election prior to June 30, 2017, either physically settle the transactions by issuing the total of 10.6 million of its common stock to Barclays in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially $69.84 per share) or Duke Energy can net settle the transactions in whole or in part through the delivery or receipt of cash or shares. If Duke Energy had elected to net share settle the contract as of June 30, 2016, Duke Energy would have been required to deliver 2.1 million shares. The forward sale price is subject to adjustment on a daily basis based on a floating interest rate factor and will decrease by other fixed amounts specified in the agreements. The net proceeds received upon settlement are expected to be used to finance a portion of the acquisition of Piedmont.

81


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

Until settlement of the Equity Forwards, earnings per share dilution resulting from the agreements will be determined under the treasury stock method.
Accelerated Stock Repurchase Program
On April 6, 2015, Duke Energy entered into agreements with each of Goldman, Sachs & Co. and JPMorgan Chase Bank, National Association (the Dealers) to repurchase a total of $1.5 billion of Duke Energy common stock under an accelerated stock repurchase program (the ASR). Duke Energy made payments of $750 million to each of the Dealers and was delivered 16.6 million shares, with a total fair value of $1.275 billion, which represented approximately 85 percent of the total number of shares of Duke Energy common stock expected to be repurchased under the ASR. The company recorded the $1.5 billion payment as a reduction to common stock as of April 6, 2015. In June 2015, the Dealers delivered 3.2 million additional shares to Duke Energy to complete the ASR. Approximately 19.8 million shares, in total, were delivered to Duke Energy and retired under the ASR at an average price of $75.75 per share. The final number of shares repurchased was based upon the average of the daily volume weighted average stock prices of Duke Energy’s common stock during the term of the program, less a discount.
14. STOCK-BASED COMPENSATION
For employee awards, equity classified stock-based compensation cost is measured at the service inception date or the grant date, based on the estimated achievement of certain performance metrics or the fair value of the award, and is recognized as expense or capitalized as a component of property, plant and equipment over the requisite service period.
Pretax stock-based compensation costs, the tax benefit associated with stock-based compensation expense, and stock-based compensation costs capitalized are included in the following table.
 
Three Months Ended
 
Six Months Ended
 
June 30,
 
June 30,
(in millions)
2016

 
2015

 
2016

 
2015

Restricted stock unit awards
$
10

 
$
11

 
$
17

 
$
20

Performance awards
5

 
8

 
10

 
13

Pretax stock-based compensation cost
$
15

 
$
19

 
$
27

 
$
33

Tax benefit associated with stock-based compensation expense
$
5

 
$
7

 
$
9

 
$
12

Stock-based compensation costs capitalized
1

 
1

 
2

 
2

15. EMPLOYEE BENEFIT PLANS
DEFINED BENEFIT RETIREMENT PLANS
Duke Energy maintains, and the Subsidiary Registrants participate in, qualified, non-contributory defined benefit retirement plans. The plans cover most U.S. employees using a cash balance formula. Under a cash balance formula, a plan participant accumulates a retirement benefit consisting of pay credits equal to a percentage of current eligible earnings based on age or the combination of age and years of service, and interest credits. Certain employees are covered under plans that use a final average earnings formula. Under these average earnings formulas, a plan participant accumulates a retirement benefit equal to the sum of percentages of their (i) highest three-year or four-year average earnings, (ii) highest three-year or four-year average earnings in excess of covered compensation per year of participation (maximum of 35 years) and/or (iii) highest three-year average earnings times years of participation in excess of 35 years. Duke Energy also maintains, and the Subsidiary Registrants participate in, non-qualified, non-contributory defined benefit retirement plans which cover certain executives. The qualified and non-qualified, non-contributory defined benefit plans are closed to new and rehired non-union and certain unionized employees.
Duke Energy’s policy is to fund amounts on an actuarial basis to provide assets sufficient to meet benefit payments to be paid to plan participants. The following table includes information related to the Duke Energy Registrants’ contributions to its U.S. qualified defined benefit pension plans. Duke Energy did not make any contributions to its U.S. qualified defined benefit pension plans during the six months ended June 30, 2016.
 
Six Months Ended June 30, 2015
 
 
 
Duke

 
 
 
Duke

 
Duke

 
Duke

 
Duke

 
Duke

 
Energy

 
Progress

 
Energy

 
Energy

 
Energy

 
Energy

(in millions)
Energy

 
Carolinas

 
Energy

 
Progress

 
Florida

 
Ohio

 
Indiana

Contributions
$
132

 
$
42

 
$
42

 
$
21

 
$
21

 
$
1

 
$
9

Net periodic benefit costs disclosed in the tables below represent the cost of the respective benefit plan for the periods presented. However, portions of the net periodic benefit costs disclosed in the tables below have been capitalized as a component of property, plant and equipment. Amounts presented in the tables below for the Subsidiary Registrants represent the amounts of pension and other post-retirement benefit costs allocated by Duke Energy for employees of the Subsidiary Registrants. Additionally, the Subsidiary Registrants are allocated their proportionate share of pension and post-retirement benefit costs for employees of Duke Energy’s shared services affiliate that provides support to the Subsidiary Registrants. These allocated amounts are included in the governance and shared service costs discussed in Note 8. Duke Energy uses a December 31 measurement date for its defined benefit retirement plan assets and obligations.

82


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

QUALIFIED PENSION PLANS
The following tables include the components of net periodic pension costs for qualified pension plans.
 
Three Months Ended June 30, 2016
 
 
 
Duke

 
 
 
Duke

 
Duke

 
Duke

 
Duke

 
Duke

 
Energy

 
Progress

 
Energy

 
Energy

 
Energy

 
Energy

(in millions)
Energy

 
Carolinas

 
Energy

 
Progress

 
Florida

 
Ohio

 
Indiana

Service cost
$
37

 
$
12

 
$
10

 
$
6

 
$
5

 
$
1

 
$
2

Interest cost on projected benefit obligation
83

 
22

 
27

 
13

 
14

 
5

 
7

Expected return on plan assets
(129
)
 
(36
)
 
(42
)
 
(20
)
 
(21
)
 
(7
)
 
(11
)
Amortization of actuarial loss
33

 
8

 
13

 
5

 
7

 
1

 
3

Amortization of prior service credit
(4
)
 
(2
)
 
(1
)
 
(1
)
 

 

 

Other
1

 

 

 
1

 

 

 

Net periodic pension costs
$
21

 
$
4

 
$
7

 
$
4

 
$
5

 
$

 
$
1

 
Three Months Ended June 30, 2015
 
 
 
Duke

 
 
 
Duke

 
Duke

 
Duke

 
Duke

 
Duke

 
Energy

 
Progress

 
Energy

 
Energy

 
Energy

 
Energy

(in millions)
Energy

 
Carolinas

 
Energy

 
Progress

 
Florida

 
Ohio

 
Indiana

Service cost
$
39

 
$
12

 
$
11

 
$
6

 
$
5

 
$
1

 
$
2

Interest cost on projected benefit obligation
81

 
20

 
26

 
12

 
13

 
4

 
7

Expected return on plan assets
(129
)
 
(33
)
 
(41
)
 
(21
)
 
(22
)
 
(7
)
 
(11
)
Amortization of actuarial loss
44

 
10

 
17

 
9

 
8

 
3

 
4

Amortization of prior service credit
(3
)
 
(2
)
 
(1
)
 
(1
)
 
(1
)
 

 

Other
2

 

 

 
1

 
1

 

 

Net periodic pension costs
$
34

 
$
7

 
$
12

 
$
6

 
$
4

 
$
1

 
$
2

 
Six Months Ended June 30, 2016
 
 
 
Duke

 
 
 
Duke

 
Duke

 
Duke

 
Duke

 
Duke

 
Energy

 
Progress

 
Energy

 
Energy

 
Energy

 
Energy

(in millions)
Energy

 
Carolinas

 
Energy

 
Progress

 
Florida

 
Ohio

 
Indiana

Service cost
$
73

 
$
24

 
$
21

 
$
12

 
$
10

 
$
2

 
$
4

Interest cost on projected benefit obligation
166

 
43

 
53

 
25

 
28

 
10

 
14

Expected return on plan assets
(258
)
 
(71
)
 
(84
)
 
(41
)
 
(42
)
 
(14
)
 
(21
)
Amortization of actuarial loss
66

 
16

 
27

 
11

 
14

 
2

 
6

Amortization of prior service credit
(8
)
 
(4
)
 
(2
)
 
(1
)
 

 

 

Other
4

 
1

 
1

 
1

 

 

 

Net periodic pension costs
$
43

 
$
9

 
$
16

 
$
7

 
$
10

 
$

 
$
3

 
Six Months Ended June 30, 2015
 
 
 
Duke

 
 
 
Duke

 
Duke

 
Duke

 
Duke

 
Duke

 
Energy

 
Progress

 
Energy

 
Energy

 
Energy

 
Energy

(in millions)
Energy

 
Carolinas

 
Energy

 
Progress

 
Florida

 
Ohio

 
Indiana

Service cost
$
79

 
$
25

 
$
22

 
$
12

 
$
10

 
$
2

 
$
5

Interest cost on projected benefit obligation
163

 
41

 
52

 
24

 
27

 
9

 
14

Expected return on plan assets
(258
)
 
(69
)
 
(84
)
 
(41
)
 
(44
)
 
(13
)
 
(21
)
Amortization of actuarial loss
87

 
20

 
34

 
17

 
16

 
5

 
7

Amortization of prior service credit
(7
)
 
(4
)
 
(2
)
 
(1
)
 
(1
)
 

 

Other
4

 
1

 
1

 
1

 
1

 

 

Net periodic pension costs
$
68

 
$
14

 
$
23

 
$
12

 
$
9

 
$
3

 
$
5


83


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

NON-QUALIFIED PENSION PLANS
The following tables include the components of net periodic pension costs for non-qualified pension plans for registrants with non-qualified pension costs.
 
Three Months Ended June 30, 2016
 
 
 
Duke

 
 
 
Duke

 
Duke

 
Duke

 
Energy

 
Progress

 
Energy

 
Energy

(in millions)
Energy

 
Carolinas

 
Energy

 
Progress

 
Florida

Service cost
$
1

 
$

 
$

 
$

 
$

Interest cost on projected benefit obligation
3

 
1

 
1

 
1

 
1

Amortization of actuarial loss
2

 

 

 

 

Net periodic pension costs
$
6

 
$
1

 
$
1

 
$
1

 
$
1

 
Three Months Ended June 30, 2015
 
 
 
Duke

 
 
 
Duke

 
Duke

 
Duke

 
Energy

 
Progress

 
Energy

 
Energy

(in millions)
Energy

 
Carolinas

 
Energy

 
Progress

 
Florida

Service cost
$
1

 
$

 
$

 
$

 
$

Interest cost on projected benefit obligation
3

 

 
1

 
1

 
1

Amortization of actuarial loss
1

 

 
1

 

 

Net periodic pension costs
$
5

 
$

 
$
2

 
$
1

 
$
1

 
Six Months Ended June 30, 2016
 
 
 
Duke

 
 
 
Duke

 
Duke

 
Duke

 
Energy

 
Progress

 
Energy

 
Energy

(in millions)
Energy

 
Carolinas

 
Energy

 
Progress

 
Florida

Service cost
$
1

 
$

 
$

 
$

 
$

Interest cost on projected benefit obligation
7

 
1

 
2

 
1

 
1

Amortization of actuarial loss
4

 

 
1

 

 

Net periodic pension costs
$
12

 
$
1

 
$
3

 
$
1

 
$
1

 
Six Months Ended June 30, 2015
 
 
 
Duke

 
 
 
Duke

 
Duke

 
Duke

 
Energy

 
Progress

 
Energy

 
Energy

(in millions)
Energy

 
Carolinas

 
Energy

 
Progress

 
Florida

Service cost
$
1

 
$

 
$
1

 
$

 
$

Interest cost on projected benefit obligation
7

 
1

 
2

 
1

 
1

Amortization of actuarial loss
3

 

 
1

 

 
1

Net periodic pension costs
$
11

 
$
1

 
$
4

 
$
1

 
$
2

OTHER POST-RETIREMENT BENEFIT PLANS
Duke Energy provides, and the Subsidiary Registrants participate in, some health care and life insurance benefits for retired employees on a contributory and non-contributory basis. Employees are eligible for these benefits if they have met age and service requirements at retirement, as set forth in the plans. The health care benefits include medical, dental, vision, and prescription drug coverage and are subject to certain limitations, such as deductibles and co-payments.

84


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

The following tables include the components of net periodic other post-retirement benefit costs.
 
Three Months Ended June 30, 2016
 
 
 
Duke

 
 
 
Duke

 
Duke

 
Duke

 
Duke

 
Duke

 
Energy

 
Progress

 
Energy

 
Energy

 
Energy

 
Energy

(in millions)
Energy

 
Carolinas

 
Energy

 
Progress

 
Florida

 
Ohio

 
Indiana

Service cost
$
1

 
$

 
$

 
$

 
$

 
$

 
$

Interest cost on accumulated post-retirement benefit obligation
9

 
2

 
3

 
2

 
1

 
1

 
1

Expected return on plan assets
(4
)
 
(2
)
 

 

 

 

 
(1
)
Amortization of actuarial loss (gain)
2

 
(1
)
 
6

 
3

 
3

 
(1
)
 

Amortization of prior service credit
(36
)
 
(3
)
 
(25
)
 
(17
)
 
(9
)
 

 

Net periodic other post-retirement benefit costs
$
(28
)
 
$
(4
)
 
$
(16
)
 
$
(12
)
 
$
(5
)
 
$

 
$

 
Three Months Ended June 30, 2015
 
 
 
Duke

 
 
 
Duke

 
Duke

 
Duke

 
Duke

 
Duke

 
Energy

 
Progress

 
Energy

 
Energy

 
Energy

 
Energy

(in millions)
Energy

 
Carolinas

 
Energy

 
Progress

 
Florida

 
Ohio

 
Indiana

Service cost
$
1

 
$
1

 
$
1

 
$

 
$

 
$

 
$

Interest cost on accumulated post-retirement benefit obligation
9

 
2

 
3

 
2

 
1

 
1

 
2

Expected return on plan assets
(3
)
 
(2
)
 

 

 

 

 

Amortization of actuarial loss (gain)
7

 
(1
)
 
7

 
4

 
2

 

 
(1
)
Amortization of prior service credit
(35
)
 
(3
)
 
(25
)
 
(16
)
 
(7
)
 

 

Net periodic other post-retirement benefit costs
$
(21
)
 
$
(3
)
 
$
(14
)
 
$
(10
)
 
$
(4
)
 
$
1

 
$
1

 
Six Months Ended June 30, 2016
 
 
 
Duke

 
 
 
Duke

 
Duke

 
Duke

 
Duke

 
Duke

 
Energy

 
Progress

 
Energy

 
Energy

 
Energy

 
Energy

(in millions)
Energy

 
Carolinas

 
Energy

 
Progress

 
Florida

 
Ohio

 
Indiana

Service cost
$
2

 
$

 
$

 
$

 
$

 
$

 
$

Interest cost on accumulated post-retirement benefit obligation
17

 
4

 
7

 
4

 
3

 
1

 
2

Expected return on plan assets
(7
)
 
(4
)
 

 

 

 

 
(1
)
Amortization of actuarial loss (gain)
3

 
(2
)
 
11

 
6

 
5

 
(1
)
 
(1
)
Amortization of prior service credit
(71
)
 
(6
)
 
(51
)
 
(34
)
 
(18
)
 

 

Net periodic other post-retirement benefit costs
$
(56
)
 
$
(8
)
 
$
(33
)
 
$
(24
)
 
$
(10
)
 
$

 
$

 
Six Months Ended June 30, 2015
 
 
 
Duke

 
 
 
Duke

 
Duke

 
Duke

 
Duke

 
Duke

 
Energy

 
Progress

 
Energy

 
Energy

 
Energy

 
Energy

(in millions)
Energy

 
Carolinas

 
Energy

 
Progress

 
Florida

 
Ohio

 
Indiana

Service cost
$
3

 
$
1

 
$
1

 
$

 
$

 
$

 
$

Interest cost on accumulated post-retirement benefit obligation
18

 
4

 
7

 
4

 
3

 
1

 
2

Expected return on plan assets
(6
)
 
(4
)
 

 

 

 

 

Amortization of actuarial loss (gain)
13

 
(1
)
 
14

 
9

 
5

 

 
(1
)
Amortization of prior service credit
(70
)
 
(7
)
 
(51
)
 
(33
)
 
(16
)
 

 

Net periodic other post-retirement benefit costs
$
(42
)
 
$
(7
)
 
$
(29
)
 
$
(20
)
 
$
(8
)
 
$
1

 
$
1


85


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

EMPLOYEE SAVINGS PLAN
Duke Energy sponsors, and the Subsidiary Registrants participate in, an employee savings plan that covers substantially all U.S. employees. Most employees participate in a matching contribution formula where Duke Energy provides a matching contribution generally equal to 100 percent of employee before-tax and Roth 401(k) contributions of up to 6 percent of eligible pay per pay period. Dividends on Duke Energy shares held by the savings plan are charged to retained earnings when declared and shares held in the plan are considered outstanding in the calculation of basic and diluted earnings per share.
For new and rehired non-union and certain unionized employees who are not eligible to participate in Duke Energy’s defined benefit plans, an additional employer contribution of 4 percent of eligible pay per pay period, subject to a three-year vesting requirement, is provided to the employee’s savings plan account.
The following table presents employer contributions made by Duke Energy and expensed by the Subsidiary Registrants.
 
 
 
Duke

 
 
 
Duke

 
Duke

 
Duke

 
Duke

 
Duke

 
Energy

 
Progress

 
Energy

 
Energy

 
Energy

 
Energy

(in millions)
Energy

 
Carolinas

 
Energy

 
Progress

 
Florida

 
Ohio

 
Indiana

Three Months Ended June 30,
 
 
 
 
 
 
 
 
 
 
2016
$
39

 
$
13

 
$
12

 
$
8

 
$
4

 
$
1

 
$
2

2015
37

 
13

 
12

 
8

 
3

 
1

 
2

Six Months Ended June 30,
 
 
 
 
 
 
 
 
 
 
2016
$
91

 
$
31

 
$
27

 
$
19

 
$
8

 
$
2

 
$
4

2015
86

 
29

 
26

 
19

 
7

 
2

 
4

16. INCOME TAXES
TAXES ON FOREIGN EARNINGS
As of December 31, 2015, Duke Energy's intention was to indefinitely reinvest foreign earnings of International Energy earned after December 31, 2014. In February 2016, Duke Energy announced it had initiated a process to divest the International Energy business segment, excluding the investment in NMC. Accordingly, Duke Energy no longer intends to indefinitely reinvest the undistributed earnings of International Energy. The Company recorded U.S. income taxes of approximately $4 million and $16 million for the three and six months ended June 30, 2016, respectively, related to such earnings and will prospectively provide U.S. income taxes on future foreign earnings.
This change in the Company's intent, combined with the extension of bonus depreciation by Congress in late 2015, allows Duke Energy to more efficiently utilize foreign tax credits and reduce U.S. deferred tax liabilities associated with historic unremitted foreign earnings by approximately $95 million for the six months ended June 30, 2016.
EFFECTIVE TAX RATES
The effective tax rates from continuing operations for each of the Duke Energy Registrants are included in the following table.
 
Three Months Ended
 
Six Months Ended
 
June 30,
 
June 30,
 
2016

 
2015

 
2016

 
2015

Duke Energy
31.8
%
 
35.6
%
 
27.2
%
 
33.6
%
Duke Energy Carolinas
35.1
%
 
36.6
%
 
34.6
%
 
36.2
%
Progress Energy
36.0
%
 
39.2
%
 
36.3
%
 
37.1
%
Duke Energy Progress
35.5
%
 
40.6
%
 
35.4
%
 
36.0
%
Duke Energy Florida
37.6
%
 
38.7
%
 
37.7
%
 
38.6
%
Duke Energy Ohio
34.3
%
 
35.0
%
 
29.2
%
 
36.8
%
Duke Energy Indiana
36.1
%
 
36.4
%
 
33.1
%
 
36.5
%
The decrease in the effective tax rate for Duke Energy for the three and six months ended June 30, 2016, is driven by lower income taxes on foreign earnings due to a more efficient utilization of foreign tax credits, as described above, and favorable impacts of finalizing federal tax audits. Refer to "Taxes on Foreign Earnings" above for additional information.
The decrease in the effective tax rate for Duke Energy Carolinas for the three and six months ended June 30, 2016, is primarily due to a favorable state resolution related to prior-year tax returns and favorable impacts of finalizing tax audits.
The decrease in the effective tax rate for Progress Energy for the three months ended June 30, 2016, is primarily due to a change in tax levelization.
The decrease in the effective tax rate for Duke Energy Progress for the three months ended June 30, 2016, is primarily due to a change in tax levelization.

86


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

The decrease in the effective tax rate for Duke Energy Florida for the three months ended June 30, 2016, is primarily due to an increase in AFUDC equity.
The decrease in the effective tax rate for Duke Energy Ohio for the six months ended June 30, 2016, is primarily due to a favorable prior-period adjustment for depreciation and other property, plant and equipment.
The decrease in the effective tax rate for Duke Energy Indiana for the six months ended June 30, 2016, is primarily due to a favorable prior-period adjustment for depreciation and other property, plant and equipment.

87


PART I
DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –
DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC
Combined Notes to Condensed Consolidated Financial Statements – (Continued)
(Unaudited)

17. SUBSEQUENT EVENTS
For information on subsequent events related to acquisitions, regulatory matters, commitments and contingencies, and debt and credit facilities see Notes 2, 4, 5 and 6, respectively.

88


PART I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
The following combined Management’s Discussion and Analysis of Financial Condition and Results of Operations is separately filed by Duke Energy Corporation (collectively with its subsidiaries, Duke Energy) and Duke Energy Carolinas, LLC (Duke Energy Carolinas), Progress Energy, Inc. (Progress Energy), Duke Energy Progress, LLC (Duke Energy Progress), Duke Energy Florida, LLC (Duke Energy Florida), Duke Energy Ohio, Inc. (Duke Energy Ohio) and Duke Energy Indiana, LLC (Duke Energy Indiana) (collectively referred to as the Subsidiary Registrants). However, none of the registrants make any representation as to information related solely to Duke Energy or the Subsidiary Registrants of Duke Energy other than itself.
DUKE ENERGY
Duke Energy is an energy company headquartered in Charlotte, North Carolina. Duke Energy operates in the United States (U.S.) primarily through its wholly owned subsidiaries, Duke Energy Carolinas, Duke Energy Progress, Duke Energy Florida, Duke Energy Ohio and Duke Energy Indiana, as well as in Latin America.
When discussing Duke Energy’s consolidated financial information, it necessarily includes the results of the Subsidiary Registrants, which, along with Duke Energy, are collectively referred to as the Duke Energy Registrants.
Management’s Discussion and Analysis includes financial information prepared in accordance with generally accepted accounting principles (GAAP) in the U.S., as well as certain non-GAAP financial measures such as adjusted earnings, adjusted diluted earnings per share (EPS) and adjusted segment income, discussed below. Generally, a non-GAAP financial measure is a numerical measure of financial performance, financial position or cash flows that excludes (or includes) amounts that are included in (or excluded from) the most directly comparable measure calculated and presented in accordance with GAAP. The non-GAAP financial measures should be viewed as a supplement to, and not a substitute for, financial measures presented in accordance with GAAP. Non-GAAP measures presented herein may not be comparable to similarly titled measures used by other companies.
Management’s Discussion and Analysis should be read in conjunction with the Condensed Consolidated Financial Statements and Notes for the six months ended June 30, 2016, and with Duke Energy’s Annual Report on Form 10-K for the year ended December 31, 2015.
Acquisition of Piedmont Natural Gas
On October 24, 2015, Duke Energy entered into an Agreement and Plan of Merger (Merger Agreement) with Piedmont Natural Gas Company, Inc., (Piedmont) a North Carolina corporation. Under the terms of the Merger Agreement, Duke Energy will acquire Piedmont for approximately $4.9 billion in cash and Piedmont will become a wholly owned subsidiary of Duke Energy. In addition, Duke Energy will assume Piedmont's existing debt, which was approximately $2.0 billion at April 30, 2016, the end of Piedmont's most recent filed quarter. The excess of the purchase price over the fair value of Piedmont's assets and liabilities on the acquisition date will be recorded as goodwill. Duke Energy estimates the transaction would result in incremental goodwill of approximately $3.5 billion. Duke Energy expects to finance the transaction with a combination of debt, equity issuances and other cash sources. As of June 30, 2016, Duke Energy entered into $1.4 billion of forward-starting interest rate swaps to manage interest rate exposure for the expected financing of the Piedmont acquisition. For additional information on the forward-starting swaps, see Note 9 to the Condensed Consolidated Financial Statements, "Derivatives and Hedging."
In March 2016, Duke Energy marketed an equity offering of 10.6 million shares of Duke Energy common stock. In lieu of issuing equity at the time of the offering, Duke Energy entered into equity forward sale agreements (the Equity Forwards) with Barclays Capital, Inc. (Barclays). Duke Energy expects to settle the Equity Forwards on or around the closing date of the Piedmont acquisition. The net proceeds received upon settlement are expected to be used to finance a portion of the acquisition of Piedmont. For additional information regarding the Equity Forwards, see Note 13 to the Condensed Consolidated Financial Statements, "Common Stock."
In connection with the Merger Agreement with Piedmont, Duke Energy entered into a $4.9 billion senior unsecured bridge financing facility (Bridge Facility) with Barclays. The Bridge Facility, if drawn upon, may be used to (i) fund the cash consideration for the transaction and (ii) pay certain fees and expenses in connection with the transaction. In November 2015, Barclays syndicated its commitment under the Bridge Facility to a broader group of lenders. Duke Energy does not expect to draw upon the Bridge Facility. The amount of the Bridge Facility is reduced by any financings related to the Piedmont acquisition entered into by Duke Energy, and has accordingly been reduced to $3.2 billion as a result of the Equity Forwards and $1 billion of the commitments under a term loan amended and restated as of August 1, 2016. See Note 6 to the Condensed Consolidated Financial Statements, "Debt and Credit Facilities," for additional information.
Piedmont's shareholders have approved the company's acquisition by Duke Energy and the Federal Trade Commission (FTC) has granted early termination of the 30-day waiting period under the federal Hart-Scott-Rodino Antitrust Improvements Act of 1976. On January 15, 2016, Duke Energy and Piedmont filed an application with the North Carolina Utilities Commission (NCUC) for approval of the proposed business combination and associated financing transactions. On January 29, 2016, the NCUC approved Duke Energy's proposed financing transactions. On March 7, 2016, the Kentucky Public Service Commission (KPSC) granted Duke Energy's declaratory request that the transaction does not constitute a change in control and does not require KPSC approval. The Tennessee Regulatory Authority approved Duke Energy's and Piedmont's request of the change in control resulting from the transaction at its March 14, 2016, meeting. On June 10, 2016 the North Carolina Public Staff reached an agreement with Duke Energy and Piedmont on certain stipulations and conditions for approval of the transaction. Duke Energy and Piedmont have also entered into settlement agreements with the Environmental Defense Fund (EDF) and the Carolina Utility Customers Association, Inc. (CUCA) resolving EDF's and CUCA's issues in the case.
On July 19, 2016, the NCUC concluded an evidentiary hearing for the proposed business combination. Proposed orders are due from all parties by August 25, 2016, after which the NCUC will rule on the application. Subject to receipt of NCUC approval, and meeting closing conditions, Duke Energy and Piedmont expect to close the transaction by the end of 2016. Upon closing of the proposed acquisition, Duke Energy expects to record expenses of $175 million to $200 million, representing accruals for commitments made in conjunction with the transaction, such as funding charitable and community support contributions, professional fees and severance.

89


PART I

The Merger Agreement contains certain termination rights for both Duke Energy and Piedmont, and provides that, upon termination of the Merger Agreement under specified circumstances, Duke Energy would be required to pay a termination fee of $250 million to Piedmont and Piedmont would be required to pay Duke Energy a termination fee of $125 million.
Upon closing of the proposed acquisition of Piedmont, the chief operating decision-maker may determine that changes to business segments are necessary. The final outcome has not been determined.
See Note 4 to the Condensed Consolidated Financial Statements, "Regulatory Matters," for additional information regarding Duke Energy and Piedmont's joint investment in Atlantic Coast Pipeline, LLC (ACP).
Change In Segment Income
During the first quarter of 2016, the Duke Energy chief operating decision-maker began to evaluate interim period segment performance based on financial information that includes the impact of income tax levelization within segment income. This represents a change from the previous measure, where the interim period impacts of income tax levelization were included within Other, and therefore excluded from segment income. As a result, prior period segment results presented have been recast to conform to this change.
Potential Sale of International Energy
In February 2016, Duke Energy announced it had initiated a process to divest the International Energy business segment, excluding the equity method investment in National Methanol Company (NMC). Duke Energy is actively marketing the business. Non-binding offers have been received and are being evaluated. There is no assurance that this process will result in a transaction and the timing for execution of a potential transaction is uncertain. Proceeds from a successful sale would be used by Duke Energy to reduce debt and fund the operations and growth of domestic businesses. If the potential of a sale were to progress, it could result in classification of International Energy as assets held for sale and as a discontinued operation.
Based upon the advancement of the marketing efforts Duke Energy performed recoverability tests of the long-lived asset groups of International Energy as of June 30, 2016. As a result, Duke Energy determined the carrying value of certain assets in Central America is not fully recoverable and recorded a pretax impairment charge of $194 million, which is included within Impairment Charges on the Condensed Consolidated Statements of Operations for the three and six months ended June 30, 2016. The impairment charge represents the excess of carrying value over the estimated fair value of the assets. The fair value of the assets was primarily determined from the income approach using discounted cash flows but also considered market information obtained in 2016.
As of June 30, 2016, the International Energy segment had a carrying value of approximately $2.4 billion, adjusted for approximately $589 million of cumulative foreign currency translation losses currently classified as accumulated other comprehensive loss.
Results of Operations
In this section, Duke Energy provides analysis and discussion of earnings and factors affecting earnings on both a GAAP and non-GAAP basis.
Management evaluates financial performance in part based on non-GAAP financial measures, adjusted earnings and adjusted diluted EPS. These items represent income from continuing operations net of income (loss) attributable to noncontrolling interests, adjusted for the dollar and per-share impact of special items. Special items represent certain charges and credits, which management believes are not indicative of Duke Energy's ongoing performance, as discussed below. Management believes the presentation of adjusted earnings and adjusted diluted EPS provides useful information to investors, as it provides them an additional relevant comparison of Duke Energy’s performance across periods. Management uses these non-GAAP financial measures for planning and forecasting and for reporting results to the Duke Energy Board of Directors, employees, stockholders, analysts and investors concerning Duke Energy’s financial performance. Adjusted diluted EPS is also used as a basis for employee incentive bonuses. The most directly comparable GAAP measures for adjusted earnings and adjusted diluted EPS are Net Income Attributable to Duke Energy Corporation and Diluted EPS Attributable to Duke Energy Corporation common stockholders.
Special items included in the periods presented include the following:
Costs to achieve mergers and International impairment represent charges that result from potential or completed strategic acquisitions and divestitures that do not reflect ongoing costs of the business.
Costs savings initiatives represent restructuring charges incurred to reduce future expenses and do not represent ongoing costs.
Midwest generation operations represents the operating results of the nonregulated Midwest generation business and Duke Energy Retail Sales (collectively, the Disposal Group), which have been classified as discontinued operations. Management believes inclusion of the Disposal Group's operating results within adjusted earnings and adjusted diluted EPS results in a better reflection of Duke Energy's financial performance during the period.
Management evaluates segment performance based on segment income. Segment income is defined as income from continuing operations net of income attributable to noncontrolling interests. Segment income includes intercompany revenues and expenses that are eliminated in the Condensed Consolidated Financial Statements. Management also uses adjusted segment income as a measure of historical and anticipated future segment performance. Adjusted segment income is a non-GAAP financial measure, as it is based upon segment income adjusted for special items, which are discussed above. Management believes the presentation of adjusted segment income as presented provides useful information to investors, as it provides them with an additional relevant comparison of a segment’s performance across periods. The most directly comparable GAAP measure for adjusted segment income is segment income.
Duke Energy’s adjusted earnings, adjusted diluted EPS, and adjusted segment income may not be comparable to similarly titled measures of another company because other entities may not calculate the measures in the same manner.
See Note 3 to the Condensed Consolidated Financial Statements, “Business Segments,” for a discussion of Duke Energy’s segment structure.

90


PART I

Executive Overview
Reported EPS attributable to Duke Energy Corporation common stockholders (Reported EPS) was $0.74 for the second quarter of 2016 compared to $0.78 for the second quarter of 2015. Reported EPS was lower due to an impairment of certain assets in Central America, unrealized losses on interest rate swaps related to the proposed Piedmont acquisition, and lower revenues due to less favorable weather; partially offset by higher retail revenues from pricing and rider recoveries, and charges in the prior year related to the Disposal Group.
As discussed above, management also evaluates financial performance based on adjusted diluted EPS. Duke Energy’s second quarter 2016 adjusted diluted EPS was $1.07 compared to $0.95 for the second quarter of 2015.
The following table reconciles non-GAAP measures, including adjusted diluted EPS, to their most directly comparable GAAP measures.
 
Three Months Ended June 30, 2016
(in millions, except per-share amounts)
Regulated
Utilities

 
International
Energy

 
Commercial
Portfolio

 
Total Reportable
Segments

 
Other

 
Eliminations/ Discontinued Operations

 
Duke
Energy

 
Per
Diluted
Share

Reported Net Income Attributable to Duke Energy Corporation/Reported EPS
$
718

 
$
(102
)
 
$
14

 
$
630

 
$
(120
)
 
$
(1
)
 
$
509

 
$
0.74

Costs to achieve, mergers(a)

 

 

 

 
69

 

 
69

 
0.10

International impairment(b)

 
145

 

 
145

 

 

 
145

 
0.21

Cost savings initiatives(c)

 

 

 

 
15

 

 
15

 
0.02

Discontinued operations

 

 

 

 

 
1

 
1

 

Adjusted earnings/Adjusted EPS
$
718

 
$
43

 
$
14

 
$
775

 
$
(36
)
 
$

 
$
739

 
$
1.07

(a)
Net of $42 million tax benefit. Primarily consists of unrealized losses on forward-starting interest rate swaps utilized to manage interest rate exposure for the expected financing of the Piedmont acquisition.
(b)
Net of $49 million tax benefit. Impairment of certain assets in Central America.
(c)
Net of $9 million tax benefit. Primarily consists of severance costs.
 
Three Months Ended June 30, 2015
(in millions, except per-share amounts)
Regulated
Utilities

 
International
Energy

 
Commercial
Portfolio

 
Total Reportable
Segments

 
Other

 
Eliminations/ Discontinued Operations

 
Duke
Energy

 
Per
Diluted
Share

Reported Net Income Attributable to Duke Energy Corporation/Reported EPS
$
632

 
$
52

 
$
(30
)
 
$
654

 
$
(51
)
 
$
(60
)
 
$
543

 
$
0.78

Costs to achieve Progress Energy merger(a)

 

 

 

 
14

 

 
14

 
0.02

Discontinued operations

 

 
41

 
41

 

 
60

 
101

 
0.15

Adjusted earnings/Adjusted EPS
$
632

 
$
52

 
$
11

 
$
695

 
$
(37
)
 
$

 
$
658

 
$
0.95

(a)
Net of $8 million tax benefit.
The increase in adjusted earnings for the three months ended June 30, 2016, compared to the same period in 2015, was primarily due to:
Higher regulated results due to increased retail pricing and riders, including energy efficiency programs, partially offset by less favorable weather;
Lower operations and maintenance expense primarily due to lower outage costs and cost savings initiatives;
Improved results in Brazil primarily due to favorable hydrology, partially offset by weaker foreign currency exchange rates; and
Incremental earnings from the additional ownership interest in generating assets acquired from North Carolina Eastern Municipal Power Agency (NCEMPA).
Partially offset by:
Lower earnings from International Energy's equity method investment in NMC, primarily due to lower methyl tertiary butyl ether (MTBE) and methanol prices.

91


PART I

Duke Energy's Reported EPS was $1.74 for the six months ended June 30, 2016 compared to $2.01 for the six months ended June 30, 2015. Reported EPS was lower due to an impairment of certain assets in Central America, unrealized losses on interest rate swaps related to the proposed Piedmont acquisition, and lower revenues due to less favorable weather; partially offset by higher retail revenues from pricing and rider recoveries, and a favorable tax adjustment at International Energy.
As discussed above, management also evaluates financial performance based on adjusted diluted EPS. Duke Energy’s adjusted diluted EPS was $2.20 for the six months ended June 30, 2016, which is consistent with adjusted diluted EPS for the six months ended June 30, 2015.
The following table reconciles non-GAAP measures, including adjusted diluted EPS, to their most directly comparable GAAP measures.
 
Six Months Ended June 30, 2016
(in millions, except per-share amounts)
Regulated
Utilities

 
International
Energy

 
Commercial
Portfolio

 
Total Reportable
Segments

 
Other

 
Eliminations/ Discontinued Operations

 
Duke
Energy

 
Per
Diluted
Share

Net Income Attributable to Duke Energy Corporation/Reported EPS
$
1,413

 
$
21

 
$
41

 
$
1,475

 
$
(274
)
 
$
2

 
$
1,203

 
$
1.74

Costs to achieve, mergers(a)

 

 

 

 
143

 

 
143

 
0.21

International impairment(b)

 
145

 

 
145

 

 

 
145

 
0.21

Cost savings initiatives(c)

 

 

 

 
27

 

 
27

 
0.04

Discontinued operations

 

 

 

 

 
(2
)
 
(2
)
 

Adjusted earnings/Adjusted EPS
$
1,413

 
$
166

 
$
41

 
$
1,620

 
$
(104
)
 
$

 
$
1,516

 
$
2.20

(a)
Net of $88 million tax benefit. Primarily consists of unrealized losses on forward-starting interest rate swaps utilized to manage interest rate exposure for the expected financing of the Piedmont acquisition.
(b)
Net of $49 million tax benefit. Impairment of certain assets in Central America.
(c)
Net of $17 million tax benefit. Primarily consists of severance costs.
 
Six Months Ended June 30, 2015
(in millions, except per-share amounts)
Regulated
Utilities

 
International
Energy

 
Commercial Portfolio

 
Total Reportable
Segments

 
Other

 
Eliminations/ Discontinued Operations

 
Duke
Energy

 
Per
Diluted
Share

Net Income Attributable to Duke Energy Corporation/Reported EPS
$
1,406

 
$
88

 
$
(23
)
 
$
1,471

 
$
(94
)
 
$
30

 
$
1,407

 
$
2.01

Midwest generation operations

 

 
94

 
94

 

 
(94
)
 

 

Costs to achieve Progress Energy merger(a)

 

 

 

 
27

 

 
27

 
0.04

Discontinued operations

 

 
41

 
41

 

 
64

 
105

 
0.15

Adjusted earnings/Adjusted EPS
$
1,406

 
$
88

 
$
112

 
$
1,606

 
$
(67
)
 
$

 
$
1,539

 
$
2.20

(a)
Net of $16 million tax benefit.
The decrease in adjusted earnings for the six months ended June 30, 2016, compared to the same period in 2015, was primarily due to:
Lower results due to the absence of earnings from the Disposal Group sold in April 2015;
Increased depreciation and amortization expense primarily due to a higher amount of property, plant and equipment in service; and
Lower earnings from International Energy's equity method investment in NMC, primarily due to lower MTBE and methanol prices.
Partially offset by:
Lower income tax expense as a result of the Company's intent to no longer indefinitely reinvest the foreign earnings of the International Energy segment combined with more efficient utilization of foreign tax credits, net of additional tax expense recognized in 2016 on International Energy's unremitted earnings. See Note 16 to the Condensed Consolidated Financial Statements, "Income Taxes," for additional information;
Higher regulated results due to increased retail pricing and riders, including energy efficiency programs, partially offset by less favorable weather;
Higher results in Latin America primarily due to favorable hydrology in Brazil, partially offset by weaker foreign currency exchange rates;
Lower operations and maintenance expense primarily due to lower outage costs and cost efficiency initiatives, partially offset by an increase in storm restoration costs due to more severe winter storms in the Carolinas;
Incremental earnings from the additional ownership interest in generating assets acquired from NCEMPA; and
Reduction in weighted average shares outstanding primarily due to the prior-year accelerated stock repurchase.

92


PART I

SEGMENT RESULTS
The remaining information in this discussion of results of operations is presented on a GAAP basis.
Regulated Utilities
 
Three Months Ended June 30,
 
Six Months Ended June 30,
(in millions)
2016

 
2015

 
Variance

 
2016

 
2015

 
Variance

Operating Revenues
$
5,099

 
$
5,220

 
$
(121
)
 
$
10,358

 
$
10,943

 
$
(585
)
Operating Expenses
3,772

 
4,003

 
(231
)
 
7,739

 
8,308

 
(569
)
Gains on Sales of Other Assets and Other, net
1

 
2

 
(1
)
 
2

 
9

 
(7
)
Operating Income
1,328

 
1,219

 
109

 
2,621

 
2,644

 
(23
)
Other Income and Expenses, net
74

 
59

 
15

 
138

 
131

 
7

Interest Expense
278

 
274

 
4

 
555

 
549

 
6

Income Before Income Taxes
1,124

 
1,004

 
120

 
2,204

 
2,226

 
(22
)
Income Tax Expense
406

 
372

 
34

 
791

 
820

 
(29
)
Segment Income
$
718

 
$
632

 
$
86

 
$
1,413

 
$
1,406

 
$
7

 
 
 
 
 
 
 
 
 
 
 


Duke Energy Carolinas Gigawatt-hours (GWh) sales
20,757

 
21,306

 
(549
)
 
42,382

 
43,774

 
(1,392
)
Duke Energy Progress GWh sales
16,829

 
14,952

 
1,877

 
33,978

 
31,717

 
2,261

Duke Energy Florida GWh sales
10,646

 
10,802

 
(156
)
 
19,102

 
19,275

 
(173
)
Duke Energy Ohio GWh sales
5,796

 
6,233

 
(437
)
 
11,903

 
13,000

 
(1,097
)
Duke Energy Indiana GWh sales
8,157

 
7,705

 
452

 
17,551

 
16,433

 
1,118

Total Regulated Utilities GWh sales
62,185

 
60,998

 
1,187

 
124,916

 
124,199

 
717

Net proportional Megawatt (MW) capacity in operation
 
 
 
 


 
49,620

 
49,528

 
92

Three Months Ended June 30, 2016 as Compared to June 30, 2015
Regulated Utilities’ results were impacted by increased rate riders and retail pricing, lower operations and maintenance expenses, and an increase in wholesale power margins. These impacts were partially offset by less favorable weather in the Carolinas and Florida. The following is a detailed discussion of the variance drivers by line item.
Operating Revenues. The variance was driven primarily by:
a $223 million decrease in fuel revenues driven by lower fuel prices included in electric rates and overall lower retail volumes; and
a $43 million decrease in electric retail sales, net of fuel revenue, due to less favorable weather in the Carolinas and Florida compared to the prior year.
Partially offset by:
a $112 million increase in rate riders, including increased revenues related to energy efficiency programs and the additional ownership interest in certain generating assets acquired from NCEMPA in the third quarter of 2015, and retail electric pricing primarily due to lower sales volumes which resulted in higher average customer rates; and
a $38 million increase in wholesale power revenues, primarily due to additional volumes and capacity charges for customers served under long-term contracts, including the NCEMPA wholesale contract that became effective August 1, 2015.
Operating Expenses. The variance was driven primarily by:
a $215 million decrease in fuel expense (including purchased power and natural gas purchases for resale) primarily due to lower natural gas and coal prices, and decreased generation due to lower sales volumes; and
a $42 million decrease in operations and maintenance expense primarily due to lower outage costs and costs savings initiatives.
Other Income and Expenses, net. The variance was driven primarily by higher allowance for funds used during construction (AFUDC) equity.
Income Tax Expense. The variance was primarily due to an increase in pretax income, partially offset by a lower effective tax rate. The effective tax rates for the three months ended June 30, 2016 and 2015 were 36.1 percent and 37.1 percent, respectively. The decrease in the effective tax rate is primarily due to favorable impacts of finalizing tax audits.
Six Months Ended June 30, 2016 as Compared to June 30, 2015
Regulated Utilities’ results were impacted by increased rate riders and retail pricing, an increase in wholesale power margins and lower operations and maintenance expense. These impacts were partially offset by less favorable weather, increased depreciation and amortization expense, and higher property and other tax expense. The following is a detailed discussion of the variance drivers by line item.

93


PART I

Operating Revenues. The variance was driven primarily by:
a $635 million decrease in fuel revenues driven by lower fuel prices included in electric rates and overall lower volumes; and
a $157 million decrease in electric retail sales, net of fuel revenue, due to less favorable weather across all the jurisdictions compared to the prior year.
Partially offset by:
a $169 million increase in rate riders including increased revenues related to energy efficiency programs and the additional ownership interest in certain generating assets acquired from NCEMPA in the third quarter of 2015, and retail electric pricing primarily due to lower sales volumes, which resulted in higher average customer rates; and
a $52 million increase in wholesale power revenues, primarily due to additional volumes and capacity charges for customers served under long-term contracts, including the NCEMPA wholesale contract that became effective August 1, 2015.
Operating Expenses. The variance was driven primarily by:
a $627 million decrease in fuel expense (including purchased power and natural gas purchases for resale) primarily due to lower natural gas and coal prices, decreased generation due to lower sales volumes, and lower natural gas volumes and prices to full-service retail natural gas customers; and
a $29 million decrease in operations and maintenance expense primarily due to lower outage costs and cost savings initiatives, partially offset by higher storm restoration costs.
Partially offset by:
a $44 million increase in depreciation and amortization expense primarily due to additional plant in service, including the additional ownership interest in generating assets acquired from NCEMPA in the third quarter of 2015; and
a $40 million increase in property and other taxes primarily due to higher sales and use tax at Duke Energy Indiana and higher property taxes across multiple jurisdictions.
Income Tax Expense. The variance is due to a decrease in the effective tax rate and lower pretax income. The effective tax rates for the six months ended June 30, 2016 and 2015 were 35.9 percent and 36.8 percent, respectively.
Matters Impacting Future Regulated Utilities Results
On May 18, 2016, the North Carolina Department of Environmental Quality (NCDEQ) issued proposed risk classifications for all coal ash surface impoundments in North Carolina. All ash impoundments not previously designated as high priority by the North Carolina Coal Ash Management Act of 2014 (Coal Ash Act) were designated as intermediate risk. Certain impoundments classified as intermediate risk, however, may be reassessed in the future as low risk pursuant to legislation signed by the North Carolina governor on July 14, 2016. Regulated Utilities' estimated asset retirement obligations related to the closure of North Carolina ash impoundments are based upon the mandated closure method or a probability weighting of potential closure methods for the impoundments that may be reassessed to low risk. As the final risk ranking classifications in North Carolina are delineated, final closure plans are developed and approved for each site and the closure work progresses, and the closure method scope is determined, the complexity of work and the amount of coal combustion material could be different than estimated and, therefore, could materially impact Regulated Utilities’ financial position, results of operations and cash flows. See Note 5 to the Condensed Consolidated Financial Statements, “Commitments and Contingencies,” for additional information.
Duke Energy is a party to multiple lawsuits and could be subject to fines and other penalties related to the Dan River coal ash release and operations at other North Carolina facilities with ash basins. The outcome of these lawsuits and potential fines and penalties could have an adverse impact on Regulated Utilities’ financial position, results of operations and cash flows. See Note 5 to the Condensed Consolidated Financial Statements, “Commitments and Contingencies,” for additional information.
An order from regulatory authorities disallowing recovery of costs related to closure of ash impoundments could have an adverse impact on Regulated Utilities' financial position, results of operations and cash flows. See Note 4 to the Condensed Consolidated Financial Statements, “Regulatory Matters” and Note 9 in Duke Energy’s Annual Report on Form 10-K for the year ended December 31, 2015, "Asset Retirement Obligations," for additional information.
Duke Energy Indiana entered into a revised settlement agreement with multiple parties that will resolve all disputes, claims and issues from the IURC proceedings related to post-commercial operating performance and recovery of ongoing operating and capital costs at the Edwardsport Integrated Gasification Combined Cycle (IGCC) generating facility. The agreement is subject to Indiana Utility Regulatory Commission (IURC) approval. Pursuant to the terms of this agreement, Duke Energy Indiana recognized an impairment and related charges of $93 million for the year ended December 31, 2015. The agreement stipulates that recovery of the remaining regulatory asset will be over an eight-year period and confirms an in-service date for accounting and ratemaking purposes of June 7, 2013. The agreement, if approved, will also impose a cost cap for recoverable operations and maintenance retail costs in the second half of 2016, and 2017, as well as a cost cap for ongoing capital expenditures through 2017. As part of the settlement, Duke Energy Indiana committed to either retire or cease burning coal at Gallagher Station by December 31, 2022. If the settlement agreement is not approved, outstanding issues before the IURC related to Edwardsport would resume and the resolution of such could have an adverse impact on Regulated Utilities' financial position, results of operations and cash flows. In addition, an inability to manage operating and capital costs in accordance with caps imposed pursuant to the agreement could have an adverse impact on Regulated Utilities' financial position, results of operations and cash flows. See Note 4 to the Condensed Consolidated Financial Statements, “Regulatory Matters,” for additional information.


94


PART I

International Energy
 
Three Months Ended June 30,
 
Six Months Ended June 30,
(in millions)
2016

 
2015

 
Variance

 
2016

 
2015

 
Variance

Operating Revenues
$
270

 
$
287

 
$
(17
)
 
$
516

 
$
560

 
$
(44
)
Operating Expenses
382

 
232

 
150

 
536

 
439

 
97

Loss on Sales of Other Assets and Other, net
(1
)
 
(1
)
 

 
(1
)
 
(1
)
 

Operating (Loss) Income
(113
)
 
54

 
(167
)
 
(21
)
 
120

 
(141
)
Other Income and Expense, net
23

 
31

 
(8
)
 
39

 
45

 
(6
)
Interest Expense
22

 
22

 

 
44

 
45

 
(1
)
(Loss) Income Before Income Taxes
(112
)
 
63

 
(175
)
 
(26
)
 
120

 
(146
)
Income Tax (Benefit) Expense
(13
)
 
10

 
(23
)
 
(52
)
 
30

 
(82
)
Less: Income Attributable to Noncontrolling Interests
3

 
1

 
2

 
5

 
2

 
3

Segment (Loss) Income
$
(102
)
 
$
52

 
$
(154
)
 
$
21

 
$
88

 
$
(67
)
 
 
 
 
 
 
 
 
 
 
 
 
Sales, GWh
5,625

 
4,520

 
1,105

 
11,505

 
8,990

 
2,515

Net proportional MW capacity in operation
 
 
 
 


 
4,315

 
4,333

 
(18
)
Three Months Ended June 30, 2016 as Compared to June 30, 2015
International Energy’s results were impacted by an impairment of certain assets in Central America, lower earnings from the equity method investment in NMC and weaker exchange rates; partially offset by improved hydrology in Brazil. The following is a detailed discussion of the variance drivers by line item.
Operating Revenues. The variance was driven primarily by a $14 million decrease in Central America due to lower average prices partially offset by higher volumes. Higher revenues at Brazil due to improved hydrology were offset by weaker exchange rates.
Operating Expenses. The variance was driven primarily by:
a $181 million increase in Central America due to the asset impairment, partially offset by lower purchased power costs.
Partially offset by:
a $28 million decrease in Brazil due to lower purchased power costs due to improved hydrology and weaker foreign currency exchange rates, partially offset by higher variable costs.
Other Income and Expense, net. The variance was primarily due to lower earnings from the equity method investment in NMC, as a result of lower average MTBE and methanol prices.
Income Tax (Benefit) Expense. The variance was primarily due to a tax benefit associated with the impairment of certain assets in Central America. The effective tax rates for the three months ended June 30, 2016 and 2015 were 11.6 percent and 15.9 percent, respectively.
Six Months Ended June 30, 2016 as Compared to June 30, 2015
International Energy’s results were impacted by an impairment of certain assets in Central America, lower earnings from the equity method investment in NMC and weaker exchange rates in Latin America; partially offset by lower income taxes as a result of the Company's intent to no longer indefinitely reinvest foreign earnings and improved hydrology in Brazil. The following is a detailed discussion of the variance drivers by line item.

Operating Revenues. The variance was driven primarily by:
a $26 million decrease in Central America due to lower average prices partially offset by higher volumes; and
a $17 million decrease in Brazil due to weaker foreign currency exchange rates partially offset by higher volumes.
Operating Expenses. The variance was driven primarily by:
a $164 million increase in Central America due to the asset impairment, partially offset by lower purchased power costs.
Partially offset by:
a $66 million decrease in Brazil due to lower purchased power costs due to improved hydrology and weaker foreign currency exchange rates, partially offset by higher variable costs.
Other Income and Expense, net. The variance was primarily due to lower earnings from the equity method investment in NMC, primarily due to lower average MTBE and methanol prices, as well as lower MTBE sales volumes driven by planned maintenance; partially offset by lower butane costs.

95


PART I

Income Tax (Benefit) Expense. The variance was due to an increase in the effective tax rate and a decrease in pretax income. The increase in the effective tax rate was primarily a result of Duke Energy's ability to more efficiently utilize foreign tax credits. See Note 16 to the Condensed Consolidated Financial Statements, "Income Taxes," for additional information.
Matters Impacting Future International Energy Results
International Energy's operations include conventional hydroelectric power generation facilities located in Brazil. The weather and recessionary economic conditions in Brazil during recent years have resulted in higher energy prices, lower electricity demand and unfavorable impacts to the exchange rate of Brazil's currency. These weather and economic conditions have also resulted in lawsuits brought to the Brazilian courts by certain hydroelectric generators to limit the financial exposure to the generators. International Energy's earnings and future cash flows could be adversely impacted if reservoir levels return to the recent low levels, from a further decline of the economic and political conditions within Brazil, or as a result of the outcome of legal matters in the Brazilian courts.
International Energy's earnings from an equity method investment in NMC reflect sales of methanol and MTBE, which generate margins that are directionally correlated with Brent crude oil prices. The recent decline in crude oil prices have reduced the earnings realized from NMC. Further weakness in the market price of Brent crude oil and related commodities may result in a further decline in earnings.
In February 2016, Duke Energy announced it had initiated a process to divest the International Energy business segment, excluding the equity method investment in NMC. Duke Energy is actively marketing the business. Non-binding offers have been received and are being evaluated. There is no assurance that this process will result in a transaction and the timing for execution of a potential transaction is uncertain. Proceeds from a successful sale would be used by Duke Energy to reduce debt and fund the operations and growth of domestic businesses. If the potential of a sale were to progress, it could result in classification of International Energy as assets held for sale and as a discontinued operation. As of June 30, 2016, the International Energy segment had a carrying value of approximately $2.4 billion, adjusted for $589 million of cumulative foreign currency translation losses currently classified as accumulated other comprehensive loss.
Commercial Portfolio
 
Three Months Ended June 30,
 
Six Months Ended June 30,
(in millions)
2016

 
2015

 
Variance

 
2016

 
2015

 
Variance

Operating Revenues
$
112

 
$
75

 
$
37

 
$
226

 
$
148

 
$
78

Operating Expenses
121

 
84

 
37

 
232

 
173

 
59

Gains on Sales of Other Assets and Other, net
1

 
6

 
(5
)
 
2

 
6

 
(4
)
Operating Loss
(8
)
 
(3
)
 
(5
)
 
(4
)
 
(19
)
 
15

Other Income and Expense, net
4

 
(2
)
 
6

 
6

 

 
6

Interest Expense
11

 
10

 
1

 
23

 
22

 
1

Loss Before Income Taxes
(15
)
 
(15
)
 

 
(21
)
 
(41
)
 
20

Income Tax (Benefit) Expense
(28
)
 
15

 
(43
)
 
(61
)
 
(18
)
 
(43
)
Less: Income Attributable to Noncontrolling Interests
(1
)
 

 
(1
)
 
(1
)
 

 
(1
)
Segment Income (Loss)
$
14


$
(30
)
 
$
44

 
$
41

 
$
(23
)
 
$
64

 
 
 
 
 
 
 
 
 
 
 
 
Renewable plant production, GWh
1,758

 
1,373

 
385

 
3,818

 
2,683

 
1,135

Net proportional MW capacity in operation
 
 
 
 


 
1,978

 
1,634

 
344

Three Months Ended June 30, 2016 as Compared to June 30, 2015
Commercial Portfolio’s higher earnings are primarily due to a state tax charge recorded in the prior year related to the Disposal Group. The following is a detailed discussion of the variance drivers by line item.
Operating Revenues. The variance was driven primarily by:
a $26 million increase in electric revenues due to growth in the REC Solar business; and
a $9 million increase in electric revenues from new wind and solar generation placed in service.
Operating Expenses. The variance was driven primarily by:
a $24 million increase in operating expenses due to growth in the REC Solar business; and
a $9 million increase in operating expenses from new wind and solar generation placed in service.
Income Tax (Benefit) Expense. The variance was primarily due to a $41 million charge in the prior year related to changes in state tax apportionment factors on deferred taxes resulting from the sale of the Disposal Group in the second quarter of 2015.
Six Months Ended June 30, 2016 as Compared to June 30, 2015
Commercial Portfolio’s higher earnings are primarily due to a state tax charge recorded in the prior year related to the Midwest generation business, operating expenses recorded in the prior year related to residual Midwest Generation operations that were shifted out of Commercial Portfolio and new wind and solar generation placed in service. The following is a detailed discussion of the variance drivers by line item.

96


PART I

Operating Revenues. The variance was driven primarily by:
a $56 million increase in electric revenues due to acquisition and growth of REC Solar; and
a $31 million increase in electric revenues from new wind and solar generation placed in service and improved wind production.
Operating Expenses. The variance was driven primarily by:
a $55 million increase in operating expenses due to acquisition and growth of REC Solar; and
a $24 million increase in operating expenses from new wind and solar generation placed in service.
Partially offset by:
a $28 million decrease due to the shift of the residual Midwest generation business out of Commercial Portfolio following the sale of the Disposal Group. See Note 3 to the Condensed Consolidated Financial Statements, “Business Segments” for additional information.
Income Tax (Benefit) Expense. The variance was primarily due to a $41 million charge in the prior year related to changes in state tax apportionment factors on deferred taxes resulting from the sale of the Disposal Group in the second quarter of 2015.
Other
 
Three Months Ended June 30,
 
Six Months Ended June 30,
(in millions)
2016

 
2015

 
Variance

 
2016

 
2015

 
Variance

Operating Revenues
$
30

 
$
34

 
$
(4
)
 
$
59

 
$
61

 
$
(2
)
Operating Expenses
96

 
63

 
33

 
188

 
113

 
75

Gains on Sales of Other Assets and Other, net
4

 
6

 
(2
)
 
11

 
13

 
(2
)
Operating Loss
(62
)
 
(23
)
 
(39
)
 
(118
)
 
(39
)
 
(79
)
Other Income and Expense, net
8

 
9

 
(1
)
 
18

 
10

 
8

Interest Expense
191

 
97

 
94

 
396

 
194

 
202

Loss Before Income Taxes
(245
)
 
(111
)
 
(134
)
 
(496
)
 
(223
)
 
(273
)
Income Tax Benefit
(126
)
 
(63
)
 
(63
)
 
(226
)
 
(134
)
 
(92
)
Less: Income Attributable to Noncontrolling Interests
1

 
3

 
(2
)
 
4

 
5

 
(1
)
Net Expense
$
(120
)
 
$
(51
)
 
$
(69
)
 
$
(274
)
 
$
(94
)
 
$
(180
)
Three Months Ended June 30, 2016 as Compared to June 30, 2015
Other's higher net expense was driven by unrealized losses on forward-starting interest rate swaps related to the expected financing of the Piedmont acquisition, as well as severance accruals. The following is a detailed discussion of the variance drivers by line item.
Operating Expenses. The increase was primarily due to an increase in severance accruals.
Interest Expense. The increase was primarily due to unrealized losses on forward-starting interest rate swaps related to the expected financing of the Piedmont acquisition. For additional information see Notes 2 and 9 to the Condensed Consolidated Financial Statements, "Acquisitions and Dispositions" and "Derivatives and Hedging," respectively.
Income Tax Benefit. The variance was primarily due to an increase in pretax losses, partially offset by a decrease in the effective tax rate. The effective tax rates for the three months ended June 31, 2016 and 2015 were 51.4 percent and 56.8 percent, respectively. The decrease in the effective tax rate was primarily due to an increase in pretax losses, partially offset by favorable impacts of finalizing federal tax audits.
Six Months Ended June 30, 2016 as Compared to June 30, 2015
Other's higher net expense was due to unrealized losses on forward-starting interest rate swaps related to the expected financing of the Piedmont acquisition, as well as severance accruals. The following is a detailed discussion of the variance drivers by line item.
Operating Expenses. The increase was primarily due to severance accruals and higher charges in the current year due to the shift of the residual Midwest Generation business from the Commercial Portfolio segment to Other in the second quarter of 2015. See Note 3 to the Condensed Consolidated Financial Statements, “Business Segments” for additional information.
Interest Expense. The increase was primarily due to unrealized losses on forward-starting interest rate swaps related to the expected financing of the Piedmont acquisition. For additional information see Notes 2 and 9 to the Condensed Consolidated Financial Statements, "Acquisitions and Dispositions" and "Derivatives and Hedging," respectively.
Income Tax Benefit. The variance was primarily due to an increase in pretax losses, partially offset by a decrease in the effective tax rate. The effective tax rates for the six months ended June 30, 2016 and 2015 were 45.6 percent and 60.1 percent, respectively. The decrease in the effective tax rate was primarily due to an increase in pretax losses, partially offset by favorable impacts of finalizing federal tax audits.

97


PART I

Matters Impacting Future Other Results
Duke Energy Ohio’s retired Beckjord generating station (Beckjord), previously an asset of Commercial Portfolio, became an asset of Other after the sale of the Disposal Group. Beckjord, a nonregulated facility retired during 2014, is not subject to the U.S. Environmental Protection Agency (EPA) rule related to the disposal of Coal Combustion Residuals (CCR) from electric utilities. However, if costs are incurred as a result of environmental regulations or to mitigate risk associated with on-site storage of coal ash, the costs could have an adverse impact on Other's financial position, results of operations and cash flows.
INCOME (LOSS) FROM DISCONTINUED OPERATIONS, NET OF TAX
Three Months Ended June 30, 2016 as Compared to June 30, 2015
Discontinued Operations, Net of Tax. The variance was primarily driven by a litigation reserve recorded in 2015, as discussed in Note 5, "Commitments and Contingencies," to the Condensed Consolidated Financial Statements.
Six Months Ended June 30, 2016 as Compared to June 30, 2015
Discontinued Operations, Net of Tax. The variance was primarily driven by the Disposal Group's operating results in 2015, partially offset by a litigation reserve recorded in 2015, as discussed in Note 5, "Commitments and Contingencies," to the Condensed Consolidated Financial Statements.
DUKE ENERGY CAROLINAS
Management’s Discussion and Analysis should be read in conjunction with the accompanying Condensed Consolidated Financial Statements and Notes for the six months ended June 30, 2016 and 2015 and the Annual Report on Form 10-K for the year ended December 31, 2015.
Results of Operations
 
Six Months Ended June 30,
(in millions)
2016

 
2015

 
Variance

Operating Revenues
$
3,415

 
$
3,608

 
$
(193
)
Operating Expenses
2,470

 
2,610

 
(140
)
Operating Income
945

 
998

 
(53
)
Other Income and Expenses, net
82

 
83

 
(1
)
Interest Expense
214

 
208

 
6

Income Before Income Taxes
813

 
873

 
(60
)
Income Tax Expense
281

 
316

 
(35
)
Net Income
$
532

 
$
557

 
$
(25
)
The following table shows the percent changes in GWh sales and average number of customers. The percentages for retail customer classes represent billed sales only. Total sales includes billed and unbilled retail sales and wholesale sales to incorporated municipalities, public and private utilities and power marketers. Amounts are not weather-normalized.
(Decrease) increase over prior year
2016

Residential sales
(6.9
)%
General service sales
(1.5
)%
Industrial sales
(0.6
)%
Wholesale power sales
2.7
 %
Joint dispatch sales
(59.7
)%
Total sales
(3.2
)%
Average number of customers
1.4
 %
Six Months Ended June 30, 2016 as Compared to June 30, 2015
Operating Revenues. The variance was driven primarily by:
a $215 million decrease in fuel revenues driven by lower fuel prices included in electric retail and wholesale rates and overall lower volumes; and
a $59 million decrease in electric sales, net of fuel revenues, to retail customers due to less favorable weather compared to the prior year.
Partially offset by:
a $65 million increase in retail pricing and rate riders, which primarily reflects increased revenues related to energy efficiency programs and the expiration of the North Carolina cost of removal decrement rider.
Operating Expenses. The variance was driven primarily by:
a $195 million decrease in fuel used in electric generation and purchased power primarily related to lower natural gas and coal prices, and decreased generation due to lower sales volumes.

98


PART I

Partially offset by:
a $30 million increase in operating and maintenance expense primarily due to higher storm restoration costs and severance expenses related to cost savings initiatives; and
a $24 million increase in depreciation and amortization expense primarily due to higher amount of property, plant and equipment in service.
Income Tax Expense. The variance was primarily due to a decrease in pretax income and a reduction in the effective tax rate. The effective tax rates for the six months ended June 30, 2016 and 2015 were 34.6 percent and 36.2 percent, respectively. The decrease in the effective tax rate was primarily due to a favorable state resolution related to prior-year tax returns and favorable impacts of finalizing tax audits.
Matters Impacting Future Results
On May 18, 2016, the NCDEQ issued proposed risk classifications for all coal ash surface impoundments in North Carolina. All ash impoundments not previously designated as high priority by the Coal Ash Act were designated as intermediate risk. Certain impoundments classified as intermediate risk, however, may be reassessed in the future as low risk pursuant to legislation signed by the North Carolina governor on July 14, 2016. Duke Energy Carolinas' estimated asset retirement obligations related to the closure of North Carolina ash impoundments are based upon the mandated closure method or a probability weighting of potential closure methods for the impoundments that may be reassessed to low risk. As the final risk ranking classifications in North Carolina are delineated, final closure plans are developed and approved for each site and the closure work progresses, and the closure method scope is determined, the complexity of work and the amount of coal combustion material could be different than estimated and, therefore, could materially impact Duke Energy Carolinas' financial position, results of operations and cash flows. See Note 5 to the Condensed Consolidated Financial Statements, “Commitments and Contingencies,” for additional information.
Duke Energy Carolinas is a party to multiple lawsuits and subject to fines and other penalties related to the Dan River coal ash release and operations at other North Carolina facilities with ash basins. The outcome of these lawsuits, fines and penalties could have an adverse impact on Duke Energy Carolinas’ financial position, results of operations and cash flows. See Note 5 to the Condensed Consolidated Financial Statements, “Commitments and Contingencies,” for additional information.
An order from regulatory authorities disallowing recovery of costs related to closure of ash impoundments could have an adverse impact on Duke Energy Carolinas' financial position, results of operations and cash flows. See Notes 4 to the Condensed Consolidated Financial Statements, “Regulatory Matters” and Note 9 in Duke Energy’s Annual Report on Form 10-K for the year ended December 31, 2015, "Asset Retirement Obligations," for additional information.

99


PART I

PROGRESS ENERGY
Management’s Discussion and Analysis should be read in conjunction with the accompanying Condensed Consolidated Financial Statements and Notes for the six months ended June 30, 2016 and 2015 and the Annual Report on Form 10-K for the year ended December 31, 2015.
Results of Operations
 
Six Months Ended June 30,
(in millions)
2016

 
2015

 
Variance

Operating Revenues
$
4,680

 
$
5,012

 
$
(332
)
Operating Expenses
3,657

 
3,973

 
(316
)
Gains on Sales of Other Assets and Other, net
12

 
14

 
(2
)
Operating Income
1,035

 
1,053

 
(18
)
Other Income and Expenses, net
48

 
46

 
2

Interest Expense
320

 
334

 
(14
)
Income From Continuing Operations Before Taxes
763

 
765

 
(2
)
Income Tax Expense From Continuing Operations
277

 
284

 
(7
)
Income From Continuing Operations
486

 
481

 
5

Loss From Discontinued Operations, net of tax

 
(1
)
 
1

Net Income
486

 
480

 
6

Less: Net Income Attributable to Noncontrolling Interest
5

 
5

 

Net Income Attributable to Parent
$
481

 
$
475

 
$
6

Six Months Ended June 30, 2016 as Compared to June 30, 2015
Operating Revenues. The variance was driven primarily by:
a $336 million decrease in fuel and capacity revenues from retail customers primarily due to lower natural gas prices, changes in generation mix, and decreased demand from retail customers; partially offset by increased capacity rates to retail customers at Duke Energy Florida; and
a $67 million decrease in retail sales, net of fuel revenue, to retail customers due to less favorable weather compared to the prior year.
Partially offset by:
a $46 million increase in rate riders, including increased revenues related to energy efficiency programs and the additional ownership interest in certain generating assets acquired from NCEMPA in the third quarter of 2015, partially offset by lower nuclear cost recovery clause rider revenues due to suspending recovery for the Levy nuclear project; and
a $32 million increase in wholesale power revenues primarily due to a new NCEMPA contract effective August 1, 2015, partially offset by lower peak demand at Duke Energy Progress.
Operating Expenses. The variance was driven primarily by:
a $323 million decrease in fuel used in electric generation and purchased power primarily due to lower fuel prices, decreased demand from retail customers and changes in generation mix; and
a $16 million decrease in operations and maintenance expense primarily due to lower outage costs and cost savings initiatives, partially offset by higher storm costs, an increase in costs recoverable through the energy conservation cost recovery clause and an increase in employee benefit costs.
Partially offset by:
a $16 million increase in depreciation and amortization expense primarily due to additional plant in service, including the additional ownership interest in generating assets acquired from NCEMPA, partially offset reductions in the amounts recorded through the nuclear cost recovery clause at Duke Energy Florida.
Interest Expense. The variance was driven by accelerated Crystal River Unit 3 regulatory asset cost recovery in 2015, which resulted in a lower debt return in 2015, as well as lower outstanding debt.
Income Tax Expense. The effective tax rates for the six months ended June 30, 2016 and 2015 were 36.3 percent and 37.1 percent, respectively.

100


PART I

Matters Impacting Future Results
On May 18, 2016, the NCDEQ issued proposed risk classifications for all coal ash surface impoundments in North Carolina. All ash impoundments not previously designated as high priority by the Coal Ash Act were designated as intermediate risk. Certain impoundments classified as intermediate risk, however, may be reassessed in the future as low risk pursuant to legislation signed by the North Carolina governor on July 14, 2016. Progress Energy's estimated asset retirement obligations related to the closure of North Carolina ash impoundments are based upon the mandated closure method or a probability weighting of potential closure methods for the impoundments that may be reassessed to low risk. As the final risk ranking classifications in North Carolina are delineated, final closure plans are developed and approved for each site and the closure work progresses, and the closure method scope is determined, the complexity of work and the amount of coal combustion material could be different than estimated and, therefore, could materially impact Progress Energy's financial position, results of operations and cash flows. See Note 5 to the Condensed Consolidated Financial Statements, “Commitments and Contingencies,” for additional information.
Progress Energy is a party to multiple lawsuits and subject to fines and other penalties related to operations at certain North Carolina facilities with ash basins. The outcome of these lawsuits, fines and penalties could have an adverse impact on Progress Energy’s financial position, results of operations and cash flows. See Note 5 to the Condensed Consolidated Financial Statements, “Commitments and Contingencies,” for additional information.
An order from regulatory authorities disallowing recovery of costs related to closure of ash impoundments could have an adverse impact on Progress Energy’s financial position, results of operations and cash flows. See Notes 4 to the Condensed Consolidated Financial Statements, “Regulatory Matters” and Note 9 in Duke Energy’s Annual Report on Form 10-K for the year ended December 31, 2015, "Asset Retirement Obligations," for additional information.

101


PART I

DUKE ENERGY PROGRESS
Management’s Discussion and Analysis should be read in conjunction with the accompanying Condensed Consolidated Financial Statements and Notes for the six months ended June 30, 2016 and 2015 and the Annual Report on Form 10-K for the year ended December 31, 2015.
Results of Operations
 
Six Months Ended June 30,
(in millions)
2016

 
2015

 
Variance

Operating Revenues
$
2,520

 
$
2,642

 
$
(122
)
Operating Expenses
2,008

 
2,143

 
(135
)
Gains on Sales of Other Assets and Other, net
1

 
1

 

Operating Income
513

 
500

 
13

Other Income and Expenses, net
29

 
35

 
(6
)
Interest Expense
127

 
116

 
11

Income Before Income Taxes
415

 
419

 
(4
)
Income Tax Expense
147

 
151

 
(4
)
Net Income and Comprehensive Income
$
268

 
$
268

 
$

The following table shows the percent changes in GWh sales and average number of customers. The percentages for retail customer classes represent billed sales only. Total sales includes billed and unbilled retail sales, and wholesale sales to incorporated municipalities, public and private utilities and power marketers. Amounts are not weather-normalized.
(Decrease) Increase over prior period
2016

Residential sales
(8.9
)%
General service sales
(1.3
)%
Industrial sales
(0.3
)%
Wholesale power sales
23.4
 %
Joint dispatch sales
59.9
 %
Total sales
7.1
 %
Average number of customers
1.3
 %
Six Months Ended June 30, 2016 as Compared to June 30, 2015
Operating Revenues. The variance was driven primarily by:
a $151 million decrease in fuel revenues driven by lower natural gas prices, changes in generation mix and decreased demand from retail customers; and
a $50 million decrease in electric sales, net of fuel revenue, to retail customers due to less favorable weather compared to the prior year.
Partially offset by:
a $68 million increase in rate rider revenues due to the purchase of NCEMPA’s ownership interest in certain generating assets and energy efficiency programs; and
a $32 million increase in wholesale power revenues primarily due to a new NCEMPA contract effective August 1, 2015, partially offset by lower peak demand.
Operating Expenses. The variance was driven primarily by:
a $152 million decrease in fuel used in electric generation and purchased power primarily due to decreased demand from retail customers, lower natural gas prices, and changes in generation mix; and
a $30 million decrease in operations and maintenance expense mostly due to lower nuclear outage costs, net of nuclear levelization impacts, driven by fewer outages in 2016, partially offset by higher storm costs.
Partially offset by:
a $35 million increase in depreciation and amortization expenses primarily due to additional plant in service, including the additional ownership interest in generating assets acquired from NCEMPA in the third quarter of 2015; and
a $12 million increase in property and other taxes due to a 2015 North Carolina Franchise Tax refund and increases in current year property taxes in North Carolina and South Carolina.
Interest Expense. The variance was primarily driven by interest related to new debt issuances in 2015.
Income Tax Expense. The effective tax rates for the six months ended June 30, 2016 and 2015 were 35.4 percent and 36.0 percent, respectively.

102


PART I

Matters Impacting Future Results
On May 18, 2016, the NCDEQ issued proposed risk classifications for all coal ash surface impoundments in North Carolina. All ash impoundments not previously designated as high priority by the Coal Ash Act were designated as intermediate risk. Certain impoundments classified as intermediate risk, however, may be reassessed in the future as low risk pursuant to legislation signed by the North Carolina governor on July 14, 2016. Duke Energy Progress' estimated asset retirement obligations related to the closure of North Carolina ash impoundments are based upon the mandated closure method or a probability weighting of potential closure methods for the impoundments that may be reassessed to low risk. As the final risk ranking classifications in North Carolina are delineated, final closure plans are developed and approved for each site and the closure work progresses, and the closure method scope is determined, the complexity of work and the amount of coal combustion material could be different than estimated and, therefore, could materially impact Duke Energy Progress' financial position, results of operations and cash flows. See Note 5 to the Condensed Consolidated Financial Statements, “Commitments and Contingencies,” for additional information.
Duke Energy Progress is a party to multiple lawsuits and subject to fines and other penalties related to operations at certain North Carolina facilities with ash basins. The outcome of these lawsuits, fines and penalties could have an adverse impact on Duke Energy Progress’ financial position, results of operations and cash flows. See Note 5 to the Condensed Consolidated Financial Statements, “Commitments and Contingencies,” for additional information.
An order from regulatory authorities disallowing recovery of costs related to closure of ash impoundments could have an adverse impact on Duke Energy Progress’ financial position, results of operations and cash flows. See Notes 4 to the Condensed Consolidated Financial Statements, “Regulatory Matters” and Note 9 in Duke Energy’s Annual Report on Form 10-K for the year ended December 31, 2015, "Asset Retirement Obligations," for additional information.

103


PART I

DUKE ENERGY FLORIDA
Management’s Discussion and Analysis should be read in conjunction with the accompanying Condensed Consolidated Financial Statements and Notes for the six months ended June 30, 2016 and 2015 and the Annual Report on Form 10-K for the year ended December 31, 2015.
Results of Operations
 
Six Months Ended June 30,
(in millions)
2016

 
2015

 
Variance

Operating Revenues
$
2,157

 
$
2,367

 
$
(210
)
Operating Expenses
1,644

 
1,825

 
(181
)
Operating Income
513

 
542

 
(29
)
Other Income and Expenses, net
19

 
10

 
9

Interest Expense
81

 
99

 
(18
)
Income Before Income Taxes
451

 
453

 
(2
)
Income Tax Expense
170

 
175

 
(5
)
Net Income
$
281

 
$
278

 
$
3

The following table shows the percent changes in GWh sales and average number of customers. The percentages for retail customer classes represent billed sales only. Wholesale power sales include both billed and unbilled sales. Total sales includes billed and unbilled retail sales, and wholesale sales to incorporated municipalities, public and private utilities and power marketers. Amounts are not weather-normalized.
Increase (decrease) over prior period
2016

Residential sales
 %
General service sales
(0.4
)%
Industrial sales
(1.1
)%
Wholesale and other
1.7
 %
Total sales
(0.9
)%
Average number of customers
1.6
 %
Six Months Ended June 30, 2016 as Compared to June 30, 2015
Operating Revenues. The variance was driven primarily by:
a $185 million decrease in fuel and capacity revenues primarily due to decreased fuel prices to retail customers, partially offset by increased capacity rates to retail customers;
a $22 million decrease in rider revenues primarily due to a decrease in nuclear cost recovery clause revenues as a result of suspending Levy recovery in 2015, partially offset by an increase in energy conservation cost recovery clause and environmental cost recovery clause revenues due to higher recovery rates in 2016; and
a $17 million decrease in revenues primarily due to less favorable weather compared to the prior year.
Partially offset by:
a $17 million increase in other revenue primarily due to a transmission customer settlement charge taken in the prior year and an increase in nonregulated customer products and services in the current year.
Operating Expenses. The variance was driven primarily by:
a $170 million decrease in fuel used in electric generation and purchased power primarily due to lower fuel prices and lower usage; and
a $20 million decrease in depreciation and amortization expense primarily due to reductions in the amounts recorded through the nuclear cost recovery clause, partially offset by increased depreciation due to additional plant in service.
Partially offset by:
a $14 million increase in operations and maintenance expense primarily due to an increase in costs recoverable through the energy conservation cost recovery clause, an increase in expenses associated with fleet outages and an increase in employee benefit costs; partially offset by a decrease in expenses due to routine fleet maintenance work.
Interest Expense. The variance was driven by accelerated Crystal River Unit 3 regulatory asset cost recovery in 2015, which resulted in a lower debt return in 2015, as well as lower outstanding debt.
Income Tax Expense. The effective tax rates for the six months ended June 30, 2016 and 2015 were 37.7 percent and 38.6 percent, respectively.

104


PART I

DUKE ENERGY OHIO
Management’s Discussion and Analysis should be read in conjunction with the accompanying Condensed Consolidated Financial Statements and Notes for the six months ended June 30, 2016 and 2015 and the Annual Report on Form 10-K for the year ended December 31, 2015.
Results of Operations
 
Six Months Ended June 30,
(in millions)
2016

 
2015

 
Variance

Operating Revenues
$
944

 
$
991

 
$
(47
)
Operating Expenses
794

 
845

 
(51
)
Gains on Sales of Other Assets and Other, net
1

 
8

 
(7
)
Operating Income
151

 
154

 
(3
)
Other Income and Expenses, net
3

 
(2
)
 
5

Interest Expense
41

 
38

 
3

Income from Continuing Operations Before Income Taxes
113

 
114

 
(1
)
Income Tax Expense from Continuing Operations
33

 
42

 
(9
)
Income from Continuing Operations
80

 
72

 
8

Income from Discontinued Operations, net of tax
2

 
25

 
(23
)
Net Income
$
82

 
$
97

 
$
(15
)
The following table shows the percent changes in Regulated Utilities' GWh sales and average number of customers. The percentages for retail customer classes represent billed sales only. Total sales includes billed and unbilled retail sales and wholesale sales to incorporated municipalities, public and private utilities and power marketers. Amounts are not weather-normalized.
(Decrease) increase over prior year
2016

Residential sales
(9.5
)%
General service sales
(2.2
)%
Industrial sales
(0.9
)%
Wholesale power sales
(76.9
)%
Total sales
(8.4
)%
Average number of customers
0.7
 %
Six Months Ended June 30, 2016 as Compared to June 30, 2015
Operating Revenues. The variance was driven primarily by:
a $45 million decrease in fuel revenues driven by lower electric fuel and natural gas prices and decreased sales volumes; and
a $15 million decrease due to less favorable weather compared to the prior year.
Partially offset by:
a $23 million increase in the energy efficiency rider due to a prior year unfavorable regulatory order limiting the ability to utilize energy efficiency banked savings.
Operating Expenses. The variance was driven by a $51 million decrease in cost of natural gas, primarily due to decreased sales volumes and lower natural gas prices.
Income Tax Expense. The variance was primarily due to a decrease in the effective tax rate. The effective tax rates for the six months ended June 30, 2016 and 2015 were 29.2 percent and 36.8 percent, respectively. The decrease in the effective tax rate was primarily due to a favorable prior-period adjustment for depreciation and other property, plant and equipment.
Discontinued Operations, Net of Tax. The variance was primarily driven by the Disposal Group's operating results in 2015.
Matters Impacting Future Results
An order from regulatory authorities disallowing recovery of costs related to closure of ash basins could have an adverse impact on Duke Energy Ohio's financial position, results of operations and cash flows. See Notes 4 to the Condensed Consolidated Financial Statements, “Regulatory Matters” and Note 9 in Duke Energy’s Annual Report on Form 10-K for the year ended December 31, 2015, "Asset Retirement Obligations," for additional information.
Beckjord, a facility retired during 2014, is not subject to the EPA rule related to the disposal of CCR from electric utilities. However, if costs are incurred as a result of environmental regulations or to mitigate risk associated with on-site storage of coal ash at the facility, the costs could have an adverse impact on Duke Energy Ohio's financial position, results of operations and cash flows.

105


PART I

DUKE ENERGY INDIANA
Management’s Discussion and Analysis should be read in conjunction with the accompanying Condensed Consolidated Financial Statements and Notes for the six months ended June 30, 2016 and 2015 and the Annual Report on Form 10-K for the year ended December 31, 2015.
Results of Operations
 
Six Months Ended June 30,
(in millions)
2016

 
2015

 
Variance

Operating Revenues
$
1,416

 
$
1,474

 
$
(58
)
Operating Expenses
1,066

 
1,119

 
(53
)
Gains of Sales of Other Assets and Other, net

 
1

 
(1
)
Operating Income
350

 
356

 
(6
)
Other Income and Expenses, net
10

 
9

 
1

Interest Expense
91

 
88

 
3

Income Before Income Taxes
269

 
277

 
(8
)
Income Tax Expense
89

 
101

 
(12
)
Net Income
$
180

 
$
176

 
$
4

The following table shows the percent changes in GWh sales and average number of customers. The percentages for retail customer classes represent billed sales only. Total sales includes billed and unbilled retail sales and wholesale sales to incorporated municipalities, public and private utilities and power marketers. Amounts are not weather-normalized.
(Decrease) increase over prior year
2016

Residential sales
(8.7
)%
General service sales
(2.9
)%
Industrial sales
0.9
 %
Wholesale power sales
64.3
 %
Total sales
6.8
 %
Average number of customers
1.0
 %
Six Months Ended June 30, 2016 as Compared to June 30, 2015
Operating Revenues. The variance was driven primarily by:
a $67 million decrease in fuel revenues, including emission allowances, primarily due to a decrease in fuel prices and lower sales volumes; and
a $15 million decrease in electric sales, net of fuel revenue, to retail customers due to less favorable weather compared to the prior year.
Partially offset by:
a $20 million increase in retail pricing and rate rider revenues due to increased revenues related to clean coal equipment.
Operating Expenses. The variance was driven primarily by:
an $81 million decrease in fuel used in electric generation and purchased power primarily due to lower fuel prices; and
a $10 million decrease in operations and maintenance expense due to a decrease in outage work at generation plants.
Partially offset by:
a $27 million increase in property and other taxes, primarily driven by higher sales and use tax due to the partial reversal in 2015 of a tax reserve upon settlement of the matter; and
an $11 million increase in depreciation and amortization expenses primarily due to a higher amount of property, plant and equipment in service.
Income Tax Expense. The variance was primarily due to a decrease in the effective tax rate. The effective tax rates for the six months ended June 30, 2016 and 2015 were 33.1 percent and 36.5 percent, respectively. The decrease in the effective tax rate was primarily due to a favorable prior-period adjustment for depreciation and other property, plant and equipment.
Matters Impacting Future Results
On April 17, 2015, the EPA published in the Federal Register a rule to regulate the disposal of CCR from electric utilities as solid waste. Duke Energy Indiana has interpreted the rule to identify the coal ash basin sites impacted and has assessed the amounts of coal ash subject to the rule and a method of compliance. Duke Energy Indiana's interpretation of the requirements of the CCR rule is subject to potential legal challenges and further regulatory approvals, which could result in additional ash basin closure requirements, higher costs of compliance and greater asset retirement obligations. An order from regulatory authorities disallowing recovery of costs related to closure of ash basins could have an adverse impact on Duke Energy Indiana's financial position, results of operations and cash flows.

106


PART I

Duke Energy Indiana entered into a revised settlement agreement with multiple parties that will resolve all disputes, claims and issues from the IURC proceedings related to post-commercial operating performance and recovery of ongoing operating and capital costs at the Edwardsport IGCC generating facility. The agreement is subject to IURC approval. Pursuant to the terms of this agreement, Duke Energy Indiana recognized an impairment and related charges of $93 million for the year ended December 31, 2015. The agreement stipulates that recovery of the remaining regulatory asset will be over an eight-year period and confirms an in-service date for accounting and ratemaking purposes of June 7, 2013. The agreement, if approved, will also impose a cost cap for recoverable operations and maintenance retail costs in the second half of 2016, and 2017, as well as a cost cap for ongoing capital expenditures through 2017. As part of the settlement, Duke Energy Indiana committed to either retire or cease burning coal at Gallagher Station by December 31, 2022. If the settlement agreement is not approved, outstanding issues before the IURC related to Edwardsport would resume and the resolution of such could have an adverse impact on Duke Energy Indiana's financial position, results of operations and cash flows. In addition, an inability to manage operating and capital costs in accordance with caps imposed pursuant to the agreement could have an adverse impact on Duke Energy Indiana's financial position, results of operations and cash flows. See Note 4 to the Condensed Consolidated Financial Statements, “Regulatory Matters,” for additional information.
Duke Energy Indiana agreed as part of the grid infrastructure improvement plan to defer depreciation and other post-in-service carrying costs related to a planned automated metering infrastructure (AMI) project until the next retail base rate case. Duke Energy Indiana also agreed to withdraw its request for the creation of a regulatory asset for the remaining book value of existing meters that would be replaced as part of the AMI project. If Duke Energy Indiana proceeds with the AMI project, an impairment charge could be incurred for some or all of the remaining book value of the existing meters. See Note 4 to the Condensed Consolidated Financial Statements, “Regulatory Matters,” for additional information.

107


PART I

LIQUIDITY AND CAPITAL RESOURCES
Sources and Uses of Cash
Duke Energy relies primarily upon cash flows from operations, debt issuances and its existing cash and cash equivalents to fund its domestic liquidity and capital requirements. Duke Energy’s capital requirements arise primarily from capital and investment expenditures, repaying long-term debt and paying dividends to shareholders. See Duke Energy’s Annual Report on Form 10-K for the year ended December 31, 2015, for a summary and detailed discussion of primary sources and uses of cash for 2016 to 2018.
On October 24, 2015, Duke Energy entered into a Merger Agreement with Piedmont, a North Carolina corporation. Under the terms of the Merger Agreement, Duke Energy will acquire Piedmont for $4.9 billion in cash. In addition, Duke Energy will assume Piedmont's existing debt, which was approximately $2.0 billion at April 30, 2016, the end of Piedmont's most recent filed fiscal quarter. Duke Energy expects to finance the transaction with a combination of debt, equity issuances and other cash sources. As of June 30, 2016, Duke Energy had entered into $1.4 billion of forward-starting interest rate swaps to manage interest rate exposure for the expected financing of the Piedmont acquisition. For additional information on the Piedmont acquisition, refer to Note 2 to the Condensed Consolidated Financial Statements, “Acquisitions and Dispositions."
In March 2016, Duke Energy marketed an equity offering of 10.6 million shares of common stock. In lieu of issuing equity at the time of the offering, Duke Energy entered into the Equity Forwards with Barclays. Duke Energy expects to settle the Equity Forwards on or around the closing date of the Piedmont acquisition. The net proceeds received upon settlement are expected to be used to finance a portion of the acquisition of Piedmont. For additional information regarding the Equity Forwards, see Note 13 to the Condensed Consolidated Financial Statements, "Common Stock."
The Subsidiary Registrants generally maintain minimal cash balances and use short-term borrowings to meet their working capital needs and other cash requirements. The Subsidiary Registrants, excluding Progress Energy (Parent), support their short-term borrowing needs through participation with Duke Energy and certain of its other subsidiaries in a money pool arrangement. The companies with short-term funds may provide short-term loans to affiliates participating under this arrangement.
Duke Energy and the Subsidiary Registrants, excluding Progress Energy (Parent), may also use short-term debt, including commercial paper and the money pool, as a bridge to long-term debt financings. The levels of borrowing may vary significantly over the course of the year due to the timing of long-term debt financings and the impact of fluctuations in cash flows from operations. From time to time, Duke Energy’s current liabilities may at times exceed current assets resulting from the use of short-term debt as a funding source to meet scheduled maturities of long-term debt, as well as cash needs, which can fluctuate due to the seasonality of its business.
CREDIT FACILITIES AND REGISTRATION STATEMENTS
Master Credit Facility Summary
Duke Energy has a Master Credit Facility with a capacity of $7.5 billion through January 2020. The Duke Energy Registrants, excluding Progress Energy (Parent), have borrowing capacity under the Master Credit Facility up to a specified sublimit for each borrower. Duke Energy has the unilateral ability at any time to increase or decrease the borrowing sublimits of each borrower, subject to a maximum sublimit for each borrower. The amount available under the Master Credit Facility has been reduced to backstop issuances of commercial paper, certain letters of credit and variable-rate demand tax-exempt bonds that may be put to the Duke Energy Registrants at the option of the holder. Duke Energy Carolinas and Duke Energy Progress are also required to each maintain $250 million of available capacity under the Master Credit Facility as security to meet obligations under plea agreements reached with the U.S. Department of Justice in 2015 related to violations at North Carolina facilities with ash basins. The table below includes the current borrowing sublimits and available capacity under the Master Credit Facility.
 
June 30, 2016
 
 
 
Duke

 
Duke

 
Duke

 
Duke

 
Duke

 
Duke

 
Duke

 
Energy

 
Energy

 
Energy

 
Energy

 
Energy

 
Energy

(in millions)
Energy

 
(Parent)

 
Carolinas

 
Progress

 
Florida

 
Ohio

 
Indiana

Facility size(a)
$
7,500

 
$
3,475

 
$
800

 
$
1,000

 
$
1,200

 
$
425

 
$
600

Reduction to backstop issuances
 
 
 
 
 
 
 
 
 
 
 
 
 
Commercial paper(b)
(1,673
)
 
(992
)
 
(300
)
 
(159
)
 
(47
)
 
(25
)
 
(150
)
Outstanding letters of credit
(77
)
 
(70
)
 
(4
)
 
(2
)
 
(1
)
 

 

Tax-exempt bonds
(116
)
 

 
(35
)
 

 

 

 
(81
)
Coal ash set-aside
(500
)
 

 
(250
)
 
(250
)
 

 

 

Available capacity
$
5,134


$
2,413


$
211


$
589


$
1,152


$
400


$
369

(a)
Represents the sublimit of each borrower.
(b)
Duke Energy issued $625 million of commercial paper and loaned the proceeds through the money pool to Duke Energy Carolinas, Duke Energy Progress, Duke Energy Ohio and Duke Energy Indiana. The balances are classified as Long-Term Debt Payable to Affiliated Companies in the Condensed Consolidated Balance Sheets.
Piedmont Bridge Facility
In connection with the Merger Agreement with Piedmont, Duke Energy entered into a $4.9 billion Bridge Facility with Barclays. The Bridge Facility, if drawn upon, may be used (i) to fund the cash consideration for the transaction and (ii) to pay certain fees and expenses in connection with the transaction. In November 2015, Barclays syndicated its commitment under the Bridge Facility to a broader group of lenders. Duke Energy does not expect to draw upon the Bridge Facility. The amount of the Bridge Facility is reduced by any financings related to the Piedmont acquisition entered into by Duke Energy, and has accordingly been reduced to approximately $3.2 billion as a result of the Equity Forwards described above and $1 billion of commitments under a term loan amended and restated as of August 1, 2016, described below.

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Term Loan Facility
On February 22, 2016, Duke Energy entered into a six-month term loan facility with commitments totaling $1.0 billion (the February 2016 Term Loan). As of June 30, 2016, $100 million was outstanding under the February 2016 Term Loan. On August 1, 2016, Duke Energy and each of the lenders under the February 2016 Term Loan amended and restated certain terms of this facility, resulting in aggregate commitments of $1.5 billion and extending the maturity date to July 31, 2017. 
As of August 1, 2016, $100 million has been drawn under the amended and restated term loan (the August 2016 Term Loan). The remaining $1.4 billion of commitments under the August 2016 Term Loan can be drawn in up to two separate borrowings, which must occur no later than 90 calendar days following August 1, 2016. Any borrowings under the August 2016 Term Loan will be used to manage short-term liquidity, including funding a portion of the Piedmont acquisition, and for general corporate purposes. The terms and conditions of the August 2016 Term Loan are generally consistent with those governing Duke Energy’s Master Credit Facility.
Solar Facilities Financing
In August 2016, Emerald State Solar, LLC, an indirect wholly owned subsidiary of Duke Energy, entered into a portfolio financing of approximately 22 North Carolina Solar facilities. The $333 million term loan facility consists of Tranche A of $228 million due in June 2034 secured by substantially all the assets of the solar facilities and Tranche B of $105 million due in June 2020 secured by an Equity Contribution Agreement with Duke Energy. The initial interest rate on the loans is six months LIBOR plus an applicable margin. The initial applicable margin is 1.75 percent with 0.125 percent increases every three years thereafter. In connection with this debt issuance, Emerald State Solar, LLC entered into two interest rate swaps to convert the substantial majority of the loan interest payments from variable rates to fixed rates of approximately 1.81 percent for Tranche A and 1.38 percent for Tranche B, plus the applicable margin.
Shelf Registration
In September 2013, Duke Energy filed a Form S-3 with the Securities and Exchange Commission (SEC). Under this Form S-3, which is uncapped, the Duke Energy Registrants, excluding Progress Energy, may issue debt and other securities in the future at amounts, prices and with terms to be determined at the time of future offerings. The registration statement also allows for the issuance of common stock by Duke Energy. Duke Energy will file a new Form S-3 to be effective prior to the expiration of the current registration statement in September 2016.
DEBT MATURITIES
The following table shows the significant components of Current maturities of long-term debt on the Condensed Consolidated Balance Sheets. The Duke Energy Registrants currently anticipate satisfying these obligations with cash on hand and proceeds from additional borrowings.
(in millions)
Maturity Date
 
Interest Rate

 
June 30, 2016

Unsecured Debt
 
 
 
 
 
Duke Energy (Parent)
November 2016
 
2.150
%
 
$
500

Duke Energy (Parent)
April 2017
 
1.009
%
 
400

Duke Energy
May 2017
 
15.530
%
 
56

Secured Debt
 
 
 
 
 
Duke Energy
June 2017
 
2.075
%
 
45

First Mortgage Bonds
 
 
 
 
 
Duke Energy Indiana
July 2016
 
0.979
%
 
150

Duke Energy Carolinas
December 2016
 
1.750
%
 
350

Duke Energy Progress
March 2017
 
0.880
%
 
250

Tax-exempt Bonds
 
 
 
 
 
Duke Energy Carolinas
February 2017
 
3.600
%
 
77

Duke Energy Ohio(a)
August 2027
 
1.280
%
 
50

Duke Energy Indiana(b)
May 2035
 
1.092
%
 
44

Other(c)
 
 
 
 
420

Current maturities of long-term debt
 
 
 
 
$
2,342

(a)
Represents Duke Energy Kentucky, Inc.'s bonds with a mandatory put in December 2016.
(b)
The bonds have a mandatory put in December 2016.
(c)
Includes capital lease obligations, amortizing debt and small bullet maturities.

CASH FLOWS FROM OPERATING ACTIVITIES
The relatively stable operating cash flows of Regulated Utilities compose a substantial portion of Duke Energy’s cash flows from operations. Regulated Utilities’ cash flows from operations are primarily driven by sales of electricity and natural gas and costs of operations. Weather conditions, commodity price fluctuations and unanticipated expenses, including unplanned plant outages, storms and legal costs and related settlements, can affect the timing and level of cash flows from operations.
Cash flows from operations are subject to a number of other factors, including but not limited to regulatory constraints, economic trends and market volatility (see “Item 1A. Risk Factors,” in the Duke Energy Registrants’ Annual Report on Form 10-K for the year ended December 31, 2015, for additional information).

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PART I

At June 30, 2016, Duke Energy had cash and cash equivalents of $676 million, of which $454 million is held by entities domiciled in foreign jurisdictions. In December 2014, Duke Energy declared a taxable dividend of historical foreign earnings in the form of notes payable to repatriate approximately $2.7 billion of cash held and expected to be generated by International Energy over a period of up to eight years. As of June 30, 2016, approximately $1.6 billion has been remitted.
Proceeds received from the notes described above or resulting from a sale of International Energy would be used by Duke Energy to reduce debt and fund the operations and growth of domestic businesses. For further information on the potential sale of International Energy, refer to Note 2 to the Condensed Consolidated Financial Statements, "Acquisitions and Dispositions."
As of December 31, 2015, Duke Energy’s intention was to indefinitely reinvest foreign earnings of International Energy earned after December 31, 2014. In February 2016, Duke Energy announced it had initiated a process to divest the International Energy business segment, excluding the investment in NMC. Accordingly, Duke Energy no longer intends to indefinitely reinvest the undistributed earnings of International Energy. As of June 30, 2016, Duke Energy recorded U.S. income taxes of approximately $16 million related to such earnings and will prospectively provide U.S. income taxes on future foreign earnings.
This change in Duke Energy's intent, combined with the extension of bonus depreciation by Congress in late 2015, allows Duke Energy to more efficiently utilize foreign tax credits and reduce U.S. deferred tax liabilities associated with historic unremitted foreign earnings by approximately $95 million.
Restrictive Debt Covenants
The Duke Energy Registrants’ debt and credit agreements contain various financial and other covenants. The Master Credit Facility contains a covenant requiring the debt-to-total capitalization ratio to not exceed 65 percent for each borrower. Failure to meet those covenants beyond applicable grace periods could result in accelerated due dates and/or termination of the agreements. As of June 30, 2016, each of the Duke Energy Registrants were in compliance with all covenants related to their debt agreements. In addition, some credit agreements may allow for acceleration of payments or termination of the agreements due to nonpayment, or the acceleration of other significant indebtedness of the borrower or some of its subsidiaries. None of the debt or credit agreements contain material adverse change clauses.
Credit Ratings
Credit ratings are intended to provide credit lenders a framework for comparing the credit quality of securities and are not a recommendation to buy, sell or hold. The Duke Energy Registrants’ credit ratings are dependent on the rating agencies’ assessments of their ability to meet their debt principal and interest obligations when they come due. If, as a result of market conditions or other factors, the Duke Energy Registrants are unable to maintain current balance sheet strength, or if earnings and cash flow outlook materially deteriorate, credit ratings could be negatively impacted.
The Duke Energy Registrants each hold credit ratings by Fitch Ratings, Inc. (Fitch), Moody’s Investors Service, Inc. (Moody’s) and Standard & Poor’s Rating Services (S&P). The Duke Energy Registrants' credit ratings and outlooks from Fitch, Moody's and S&P have not changed since February 2016.
Cash Flow Information
The following table summarizes Duke Energy’s cash flows.
 
 
Six Months Ended
 
 
June 30,
(in millions)
 
2016

 
2015

Cash flows provided by (used in):
 
 
 
 
Operating activities
 
$
3,206

 
$
2,879

Investing activities
 
(3,608
)
 
(294
)
Financing activities
 
221

 
(3,661
)
Net decrease in cash and cash equivalents
 
(181
)
 
(1,076
)
Cash and cash equivalents at beginning of period
 
857

 
2,036

Cash and cash equivalents at end of period
 
$
676

 
$
960

OPERATING CASH FLOWS
The following table summarizes key components of Duke Energy’s operating cash flows.
 
 
Six Months Ended
 
 
June 30,
(in millions)
 
2016

 
2015

Net income
 
$
1,211

 
$
1,414

Non-cash adjustments to net income
 
2,231

 
2,409

Contributions to qualified pension plans
 

 
(132
)
Payments for asset retirement obligations
 
(263
)
 
(125
)
Working capital
 
27

 
(687
)
Net cash provided by operating activities
 
$
3,206

 
$
2,879


110


PART I

The variance was driven primarily due to:
a $714 million increase in working capital primarily due to unrealized losses on forward-starting interest rate swaps related to the expected financing of the Piedmont acquisition, higher property tax accruals due to timing of payments, and lower coal stock inventory due to management of high inventory levels and timing of shipments partially due to higher utilization as a result of warmer than normal weather;
Partially offset by:
a $381 million decrease in net income after non-cash adjustments, primarily due to the absence of earnings from the Disposal Group sold in April 2015 and less favorable weather in 2016 compared to prior year, partially offset by increased retail pricing and riders.
INVESTING CASH FLOWS
The following table summarizes key components of Duke Energy’s investing cash flows.
 
 
Six Months Ended
 
 
June 30,
(in millions)
 
2016

 
2015

Capital, investment and acquisition expenditures
 
$
(3,529
)
 
$
(3,189
)
Available for sale securities, net
 
26

 
13

Proceeds from sales of the Disposal Group
 

 
2,792

Other investing items
 
(105
)
 
90

Net cash used in investing activities
 
$
(3,608
)
 
$
(294
)
The variance was primarily due to:
a $2,832 million decrease in proceeds mainly due to prior year sale of the Disposal Group to Dynegy; and
a $340 million increase in capital, investment and acquisition expenditures primarily due to growth in regulated generation investments, natural gas infrastructure and renewable energy projects.
FINANCING CASH FLOWS
The following table summarizes key components of Duke Energy’s financing cash flows.
 
 
Six Months Ended
 
 
June 30,
(in millions)
 
2016

 
2015

Issuance of common stock related to employee benefit plans
 
$
7

 
$
16

Issuances (Redemptions) of long-term debt, net
 
2,719

 
(672
)
Notes payable and commercial paper
 
(1,341
)
 
(365
)
Dividends paid
 
(1,140
)
 
(1,115
)
Repurchase of common shares
 

 
(1,500
)
Other financing items
 
(24
)
 
(25
)
Net cash provided by (used in) financing activities
 
$
221

 
$
(3,661
)
The variance was due primarily to:
a $3,391 million increase in proceeds from net issuances of long-term debt, driven by the issuance of $1,294 million of senior secured bonds used to finance the recovery of certain retired nuclear generation assets and other issuances primarily used to fund capital expenditures, repay debt maturities and pay down outstanding commercial paper; and
a $1,500 million decrease in cash outflows due to the prior year repurchase of 19.8 million common shares under the accelerated stock repurchase program.
Partially offset by:
a $976 million increase in net payments of notes payable and commercial paper, primarily due to repayment of commercial paper. These cash outflows were primarily made with proceeds from long-term debt issuances.

111



Summary of Significant Debt Issuances
The following table summarizes significant debt issuances (in millions).
 
 
 
 
 
Six Months Ended
 
 
 
 
 
June 30, 2016
 
 
 
 
 
 
 
Duke

 
Duke

 
Duke

 
Duke

 
Duke

 
Maturity
 
Interest

 
Duke

 
Energy

 
Energy

 
Energy

 
Energy

 
Energy

Issuance Date
Date
 
Rate

 
Energy

 
(Parent)

 
Carolinas

 
Florida

 
Ohio

 
Indiana

Unsecured
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
April 2016(a)
April 2023
 
2.875
%
 
$
350

 
$
350

 
$

 
$

 
$

 
$

First Mortgage Bonds
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
March 2016(b)
March 2023
 
2.500
%
 
500

 

 
500

 

 

 

March 2016(b)
March 2046
 
3.875
%
 
500

 

 
500

 

 

 

May 2016(c)
May 2046
 
3.750
%
 
500

 

 

 

 

 
500

June 2016(b)
June 2046
 
3.700
%
 
250

 

 

 

 
250

 

Secured Debt
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
June 2016(d)
March 2020
 
1.196
%
 
183

 

 

 
183

 

 

June 2016(d)
September 2022
 
1.731
%
 
150

 

 

 
150

 

 

June 2016(d)
September 2029
 
2.538
%
 
436

 

 

 
436

 

 

June 2016(d)
March 2033
 
2.858
%
 
250

 

 

 
250

 

 

June 2016(d)
September 2036
 
3.112
%
 
275

 

 

 
275

 

 

Total issuances
 
 
 
 
$
3,394


$
350

 
$
1,000


$
1,294


$
250


$
500

(a)
Proceeds were used to pay down outstanding commercial paper and for general corporate purposes.
(b)
Proceeds were used to fund capital expenditures for ongoing construction, capital maintenance and for general corporate purposes.
(c)
Proceeds were used to repay $325 million of unsecured debt due June 2016, $150 million of first mortgage bonds due July 2016 and for general corporate purposes.
(d)
Proceeds from the nuclear asset recovery bonds issued by Duke Energy Florida Project Finance, LLC (DEFPF), a bankruptcy remote subsidiary of Duke Energy Florida, were used to acquire nuclear asset-recovery property from its parent, Duke Energy Florida. The nuclear asset-recovery bonds are payable only from and secured by the nuclear asset-recovery property. DEFPF is consolidated for financial reporting purposes; however, the nuclear asset-recovery bonds do not constitute a debt, liability or other legal obligation of, or interest in, Duke Energy Florida or any of its affiliates other than DEFPF. The assets of DEFPF, including the nuclear asset-recovery property, are not available to pay creditors of Duke Energy Florida or any of its affiliates. Duke Energy Florida used the proceeds from the sale to repay short-term borrowings under the intercompany money pool borrowing arrangement and make an equity distribution of $649 million to the ultimate parent, Duke Energy (Parent), which repaid short-term borrowings. The nuclear asset-recovery bonds are sequential pay amortizing bonds. The maturity date above represents the scheduled final maturity date for the bonds. See Notes 4 and 12 to the Condensed Consolidated Financial Statements, "Regulatory Matters" and "Variable Interest Entities," respectively, for additional information.
OTHER MATTERS
Environmental Regulations
Duke Energy is subject to international, federal, state and local regulations regarding air and water quality, hazardous and solid waste disposal and other environmental matters. The Subsidiary Registrants are subject to federal, state and local regulations regarding air and water quality, hazardous and solid waste disposal and other environmental matters. These regulations can be changed from time to time and result in new obligations of the Duke Energy Registrants.
The following sections outline various proposed and recently enacted regulations that may impact the Duke Energy Registrants. Refer to Note 4 to the Condensed Consolidated Financial Statements, "Regulatory Matters," for further information regarding potential plant retirements and regulatory filings related to the Duke Energy Registrants.
Coal Combustion Residuals
On April 17, 2015, the EPA published in the Federal Register a rule to regulate the disposal of CCR from electric utilities as solid waste. The federal regulation, which became effective in October 2015, classifies CCR as nonhazardous waste under Subtitle D of the Resource Conservation and Recovery Act and allows for beneficial use of CCR with some restrictions. The regulation applies to all new and existing landfills, new and existing surface impoundments receiving CCR and existing surface impoundments that are no longer receiving CCR but contain liquid located at stations currently generating electricity (regardless of fuel source). The rule establishes requirements regarding landfill design, structural integrity design and assessment criteria for surface impoundments, groundwater monitoring and protection procedures and other operational and reporting procedures to ensure the safe disposal and management of CCR. Various industry and environmental parties have appealed the EPA's CCR rule in the D.C. Circuit Court of Appeals. On April 18, 2016, the EPA filed a motion with the federal court to settle five issues raised in litigation. On June 14, 2016, the court approved the motion with respect to all of those issues. Duke Energy does not expect a material impact from the settlement or that it will result in additional asset retirement obligation adjustments.

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PART I

In addition to the requirements of the federal CCR regulation, CCR landfills and surface impoundments will continue to be independently regulated by most states. As a result of the EPA rule, the Subsidiary Registrants recorded asset retirement obligation amounts during 2015. Cost recovery for future expenditures will be pursued through the normal ratemaking process with federal and state utility commissions and via wholesale contracts, which permit recovery of necessary and prudently incurred costs associated with Duke Energy’s regulated operations. For more information, see Note 9, "Asset Retirement Obligations," in Duke Energy’s Annual Report on Form 10-K for the year ended December 31, 2015.
Beckjord, a facility retired during 2014, is not subject to the recently enacted EPA rule related to the disposal of CCR from electric utilities. However, if costs are incurred as a result of environmental regulations or to mitigate risk associated with on-site storage of coal ash at the facility, the costs could have an adverse impact on Duke Energy Ohio's financial position, results of operations and cash flows. Costs incurred by Ohio Valley Electric Corporation (OVEC) related to environmental regulations could also have an adverse impact on Duke Energy Ohio's financial position, results of operations and cash flows.
Coal Ash Management Act of 2014
On September 20, 2014, the Coal Ash Act became law and was amended on June 24, 2015, by the North Carolina Mountain Energy Act. The Coal Ash Act, as amended, established requirements regarding the use and closure of existing ash impoundments, the disposal of ash at active coal plants and the handling of surface and groundwater impacts from ash basins in North Carolina. The Coal Ash Act, as amended, deemed eight ash impoundments at four facilities to be high priority and requires closure no later than August 1, 2019, with a potential extension for closure of the Asheville impoundment until 2022. The Coal Ash Act required state regulators to provide risk ranking classifications for the remaining 25 ash impoundments at 10 North Carolina facilities.
In January 2016, NCDEQ published draft proposed risk classifications for sites not specifically delineated by the Coal Ash Act as high priority. These risk rankings were generally determined based on three primary criteria: structural integrity of the impoundments and impact to both surface and groundwater. NCDEQ categorized 12 basins at four sites as intermediate risk and four basins at three plants as low risk. Basins at high priority sites (Dan River, Riverbend, Asheville and Sutton) require closure through excavation including a combination of transferring the ash to an appropriate engineered landfill or conversion of the ash for beneficial use. Closure of high priority basins is required to be completed no later than August 1, 2019, except for Asheville which is required to be completed no later than August 1, 2022. Intermediate risk basins require closure through excavation including a combination of converting the basin to a lined industrial landfill, transferring of the ash to an appropriate engineered landfill or conversion of the ash for beneficial use. Closure of intermediate risk basins is required to be completed no later than December 31, 2024. Low risk basins require closure through either the combination of the installation and maintenance of a cap system and groundwater monitoring system designed to minimize infiltration and erosion or other closure options available to intermediate-risk basins. Closure of low risk basins is required to be completed no later than December 31, 2029. NCDEQ also categorized nine basins at six plants as “low-to-intermediate” risk, thereby not assigning a definitive risk ranking at that time. On May 18, 2016, the NCDEQ issued new proposed risk classifications, ranking all originally proposed low risk and "low-intermediate" risk sites as intermediate.
On July 14, 2016, the Governor of North Carolina signed legislation which amends the Coal Ash Act and requires Duke Energy to undertake dam improvement projects and to provide access to a permanent alternative drinking water source to certain residents within a half mile of coal ash basin compliance boundaries and to certain other potentially impacted residents. The new legislation also ranks basins at the H.F. Lee, Cape Fear and Weatherspoon stations as intermediate risk consistent with Duke Energy's previously announced plans to excavate those basins. These specific intermediate basins require closure through excavation including a combination of transferring ash to an appropriate engineered landfill or conversion of the ash for beneficial use. Closure of these specific intermediate basins is required to be completed no later than August 1, 2028. Additionally, the new legislation requires the installation and operation of three large-scale coal ash beneficiation projects which are expected to produce reprocessed ash for use in the concrete industry. Closure of basins at sites with these beneficiation projects are required to be completed no later than December 31, 2029. Upon satisfactory completion of the dam improvement projects and installation of alternate drinking water sources by October 15, 2018, the legislation requires NCDEQ to reclassify intermediate risk sites, excluding H.F. Lee, Cape Fear and Weatherspoon, as low risk.
Per the Coal Ash Act, final proposed classifications were to be subject to Coal Ash Management Commission (Coal Ash Commission) approval. In March 2016, the Coal Ash Commission created by the Coal Ash Act was disbanded by the Governor of North Carolina based on a North Carolina Supreme Court ruling regarding the constitutionality of the body. The new legislation eliminates the Coal Ash Commission and transfers responsibility for ash basin closure oversight to the NCDEQ.
Estimated asset retirement obligations have been recognized based on the assigned risk categories based on a probability weighting of potential closure methods. Actual closure costs incurred could be materially different from current estimates that form the basis of the recorded asset retirement obligations. Costs incurred have been deferred as regulatory assets and recovery will be pursued through the normal ratemaking process with federal and state utility commissions, which permit recovery of necessary and prudently incurred costs associated with Duke Energy’s regulated operations.
Mercury and Air Toxics Standards
The final Mercury and Air Toxics Standards (MATS) rule was issued on February 16, 2012. The rule established emission limits for hazardous air pollutants from new and existing coal-fired and oil-fired steam electric generating units. The rule required sources to comply with emission limits by April 16, 2015, or by April 16, 2016, with approved extension. Strategies to achieve compliance included installation of new air emission control equipment, development of monitoring processes, fuel switching and acceleration of retirement for some coal-fired electric-generation units. All of Duke Energy's coal-fired units are in compliance with the emission limits, work practices standards and other requirements of the MATS rule. For additional information, refer to Note 4 of the Condensed Consolidated Financial Statements, “Regulatory Matters,” regarding potential plant retirements.

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PART I

Clean Water Act 316(b)
The EPA published the final 316(b) cooling water intake structure rule on August 15, 2014, with an effective date of October 14, 2014. The rule applies to 26 of the electric generating facilities the Duke Energy Registrants own and operate. The rule allows for several options to demonstrate compliance and provides flexibility to the state environmental permitting agencies to make determinations on controls, if any, that will be required for cooling water intake structures. Any required intake structure modifications and/or retrofits are expected to be installed in the 2019 to 2022 time frame. Petitions challenging the rule have been filed by several groups. It is unknown at this time when the courts will rule on the petitions.
Steam Electric Effluent Limitations Guidelines
On January 4, 2016, the final Steam Electric Effluent Limitations Guidelines (ELG) rule became effective. The rule establishes new requirements for wastewater streams associated with steam electric power generation and includes more stringent controls for any new coal plants that may be built in the future. Affected facilities must comply between 2018 and 2023, depending on timing of new Clean Water Act (CWA) permits. Most, if not all, of the steam electric generating facilities the Duke Energy Registrants own are likely affected sources. The Duke Energy Registrants are well positioned to meet the majority of the requirements of the rule due to current efforts to convert to dry ash handling. Petitions challenging the rule have been filed by several groups. On March 16, 2015, Duke Energy Indiana filed its own legal challenge to the rule with the Seventh Circuit Court of Appeals specific to the ELG for wastewater associated rule focused on the limits imposed on integrated gas combined-cycle facilities. All challenges to the rule have been consolidated in the Fifth Circuit Court of Appeals. It is unknown at this time when the courts will rule on the petitions.
Estimated Cost and Impacts of Rulemakings
Duke Energy will incur capital expenditures to comply with the environmental regulations and rules discussed above. The following table provides five-year estimated costs, excluding AFUDC, of new control equipment that may need to be installed on existing power plants primarily to comply with the Coal Ash Act requirements for conversion to dry disposal of bottom ash and fly ash, MATS, CWA 316(b) and ELGs, through December 31, 2020. The table excludes ash basin closure costs recorded as Asset retirement obligations on the Condensed Consolidated Balance Sheets. For more information related to asset retirement obligations, see Note 9 in Duke Energy’s Annual Report on Form 10-K for the year ended December 31, 2015.
(in millions)
Estimated Cost

Duke Energy
$
1,350

Duke Energy Carolinas
625

Progress Energy
350

Duke Energy Progress
300

Duke Energy Florida
50

Duke Energy Ohio
100

Duke Energy Indiana
275

The Duke Energy Registrants also expect to incur increased fuel, purchased power, operation and maintenance and other expenses, in addition to costs for replacement generation for potential coal-fired power plant retirements, as a result of these regulations. Actual compliance costs incurred may be materially different from these estimates due to reasons such as the timing and requirements of EPA regulations and the resolution of legal challenges to the rules. The Duke Energy Registrants intend to seek rate recovery of necessary and prudently incurred costs associated with regulated operations to comply with these regulations.
Cross-State Air Pollution Rule
On August 8, 2011, the final Cross-State Air Pollution Rule (CSAPR) was published in the Federal Register. The CSAPR established state-level annual sulfur dioxide (SO2) budgets and annual and seasonal nitrogen oxide (NOx) budgets that were to take effect on January 1, 2012.
On August 21, 2012, the D.C. Circuit Court vacated the CSAPR. The court also directed the EPA to continue administering the Clean Air Interstate Rule (CAIR), which required additional reductions in SO2 and NOX emissions beginning in 2015. On April 29, 2014, the Supreme Court reversed the D.C. Circuit Court’s decision, finding that with CSAPR the EPA reasonably interpreted the good neighbor provision of the CAA. The case was remanded to the D.C. Circuit Court for further proceedings consistent with the Supreme Court’s opinion. On October 23, 2014, the D.C. Circuit Court lifted the CSAPR stay, which allowed Phase 1 of the rule to take effect on January 1, 2015, terminating the CAIR. Where the CSAPR requirements are constraining, actions to meet the requirements may include purchasing emission allowances, power purchases, curtailing generation and utilizing low sulfur fuel. The CSAPR did not result in Duke Energy Registrants adding new emission controls.
On December 3, 2015, the EPA proposed a rule to lower the current CSAPR Phase 2 state ozone season NOX emission budgets for 23 Eastern states, including North Carolina, Ohio, Kentucky and Indiana. The EPA also proposed to eliminate the CSAPR Phase 2 ozone season state NOX budgets for Florida and South Carolina. The EPA proposed that these changes to state budgets take effect on May 1, 2017. The EPA has indicated that it plans to finalize a rule during the summer of 2016. The EPA's proposed changes would impose requirements to achieve emission reduction targets within short timelines and could result in an impact on the emission allowance trading market, increase costs for customers, and hamper the ability to demonstrate compliance. Duke Energy Registrants cannot predict the outcome of these proceedings.

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PART I

Carbon Pollution Standards for New, Modified and Reconstructed Power Plants
On October 23, 2015, the EPA published a final rule in the Federal Register establishing carbon dioxide (CO2) emissions limits for new, modified and reconstructed power plants. The requirements for new plants do not apply to any facility that Duke Energy currently has in operation, but would apply to plants that commenced construction after January 8, 2014. The EPA set an emissions standard for coal units of 1,400 pounds which would require the application of partial carbon capture and storage (CCS) technology for a coal unit to be able to meet the limit. Utility-scale CCS is not currently a demonstrated and commercially available technology for coal-fired electric generating units, and therefore the final standard effectively prevents the development of new coal-fired generation. The EPA set a final standard of 1,000 pounds of CO2 per gross MWh for new natural gas combined-cycle units. Petitions challenging the rule have been filed by several groups. Briefing in the case was scheduled to conclude on October 21, 2016, but on June 24, 2016, the D.C. Circuit suspended the briefing schedule and set a deadline of August 4, 2016, for parties to submit motions to amend the briefing schedule. It is unknown at this time when briefing or oral argument will occur, or when the court will rule on the petitions. The Duke Energy Registrants do not expect the impacts of the final standards will be material to Duke Energy's financial position, results of operations or cash flows.
Clean Power Plan (CPP)
On October 23, 2015, the EPA published in the Federal Register the final CPP rule that regulates CO2 emissions from existing fossil fuel-fired electric generating units. The CPP establishes CO2 emission rates and mass cap goals that apply to existing fossil fuel-fired electric generation units. Under the CPP, states are required to develop and submit a final compliance plan, or an initial plan with an extension request, to the EPA by September 6, 2016. States that receive an extension must submit a final completed plan to the EPA by September 6, 2018. The EPA intends to review and approve or disapprove state plans within 12 months of receipt. The CPP does not directly impose regulatory requirements on the Duke Energy Registrants. State implementation plans will include the regulatory requirements that will apply to the Duke Energy Registrants. The EPA also published a proposed federal plan for public comment. A federal plan would be applied to states that fail to submit a plan to EPA or where a state plan is not approved by the EPA. Comments on the proposed federal plan were due by January 21, 2016.
Legal challenges to the final CPP have been filed by stakeholders. On January 21, 2016, the U.S. Court of Appeals for the District of Columbia denied motions from petitioners to stay the CPP pending court review. On February 9, 2016, the Supreme Court granted a stay in the matter, halting implementation of the CPP until legal challenges are resolved. The states in which Duke Energy's regulated operations are located have suspended work on the CPP in response to the stay. Oral arguments before the full D.C. Circuit court are scheduled for September 27, 2016.
Compliance with CPP could cause the industry to replace coal generation with natural gas and renewables. Costs to operate coal-fired generation plants continue to grow due to increasing environmental compliance requirements, including ash management costs unrelated to CPP, which may result in the retirement of coal-fired generation plants earlier than the current end of useful lives. If the CPP is ultimately upheld by the courts and implementation goes forward, the Duke Energy Registrants could incur increased fuel, purchased power, operation and maintenance and other costs for replacement generation as a result of this rule. Due to the uncertainties related to the implementation of the CPP, the Duke Energy Registrants cannot predict the outcome of these matters.
Global Climate Change
For other information on global climate change and the potential impacts on Duke Energy, see “Other Matters” in “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in Duke Energy’s Annual Report on Form 10-K for the year ended December 31, 2015.
Nuclear Matters
For other information on nuclear matters and the potential impacts on Duke Energy, see “Other Matters” in “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in Duke Energy’s Annual Report on Form 10-K for the year ended December 31, 2015.
New Accounting Standards
See Note 1 to the Condensed Consolidated Financial Statements, “Organization and Basis of Presentation,” for a discussion of the impact of new accounting standards.
Off-Balance Sheet Arrangements
During the three and six months ended June 30, 2016, there were no material changes to Duke Energy’s off-balance sheet arrangements. For information on Duke Energy’s off-balance sheet arrangements, see “Off-Balance Sheet Arrangements” in “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in Duke Energy’s Annual Report on Form 10-K for the year ended December 31, 2015.
Contractual Obligations
Duke Energy enters into contracts that require payment of cash at certain specified periods, based on certain specified minimum quantities and prices. During the three and six months ended June 30, 2016, there were no material changes in Duke Energy’s contractual obligations. For an in-depth discussion of Duke Energy’s contractual obligations, see “Contractual Obligations” and “Quantitative and Qualitative Disclosures about Market Risk” in “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in Duke Energy’s Annual Report on Form 10-K for the year ended December 31, 2015.
Subsequent Events
See Note 17 to the Condensed Consolidated Financial Statements, “Subsequent Events,” for a discussion of subsequent events.

115



ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
During the three and six months ended June 30, 2016, there were no material changes to Duke Energy’s disclosures about market risk. For an in-depth discussion of Duke Energy’s market risks, see “Management’s Discussion and Analysis of Quantitative and Qualitative Disclosures about Market Risk” in Duke Energy’s Annual Report on Form 10-K for the year ended December 31, 2015.
ITEM 4. CONTROLS AND PROCEDURES
Disclosure Controls and Procedures
Disclosure controls and procedures are controls and other procedures that are designed to ensure that information required to be disclosed by the Duke Energy Registrants in the reports they file or submit under the Securities Exchange Act of 1934 (Exchange Act) is recorded, processed, summarized and reported within the time periods specified by the SEC rules and forms.
Disclosure controls and procedures include, without limitation, controls and procedures designed to provide reasonable assurance that information required to be disclosed by the Duke Energy Registrants in the reports they file or submit under the Exchange Act is accumulated and communicated to management, including the Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosure.
Under the supervision and with the participation of management, including the Chief Executive Officer and Chief Financial Officer, the Duke Energy Registrants have evaluated the effectiveness of their disclosure controls and procedures (as such term is defined in Rule 13a-15(e) and 15d-15(e) under the Exchange Act) as of June 30, 2016, and, based upon this evaluation, the Chief Executive Officer and Chief Financial Officer have concluded that these controls and procedures are effective in providing reasonable assurance of compliance.
Changes in Internal Control over Financial Reporting
Under the supervision and with the participation of management, including the Chief Executive Officer and Chief Financial Officer, the Duke Energy Registrants have evaluated changes in internal control over financial reporting (as such term is defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act) that occurred during the fiscal quarter ended June 30, 2016, and have concluded no change has materially affected, or is reasonably likely to materially affect, internal control over financial reporting.

116


PART II. OTHER INFORMATION


ITEM 1. LEGAL PROCEEDINGS
For information regarding legal proceedings, including regulatory and environmental matters, that became reportable events or in which there were material developments in the second quarter of 2016, see Note 4, "Regulatory Matters," and Note 5, "Commitments and Contingencies," to the Condensed Consolidated Financial Statements.
MTBE Litigation
On June 29, 2007, the New Jersey Department of Environmental Protection (NJDEP) filed suit against, among others, Duke Energy Merchants (DEM), alleging contamination of “waters of the state” by MTBE from leaking gasoline storage tanks. MTBE is a gasoline additive intended to increase the oxygen level in gasoline and make it burn cleaner. The case was moved to federal court and consolidated in an existing multidistrict litigation docket of pending MTBE cases. DEM and NJDEP have reached an agreement in principle to settle the case for a payment by DEM of $1.7 million. On February 19, 2016, the court approved a Consent Decree executed by the parties which settles the case. Payment was made in February 2016. The case was dismissed by the court on April 29, 2016. DEM is also a defendant in a similar case filed by the Commonwealth of Pennsylvania on June 19, 2014. That case has been moved to the consolidated multidistrict proceeding. Discovery in this case continues.
ITEM 1A. RISK FACTORS
In addition to the other information set forth in this report, careful consideration should be given to the factors discussed in Part I, “Item 1A. Risk Factors” in the Duke Energy Registrants’ Annual Report on Form 10-K for the year ended December 31, 2015, which could materially affect the Duke Energy Registrants’ financial condition or future results.
ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS
ISSUER PURCHASES OF EQUITY SECURITIES
There were no issuer purchases of equity securities during the second quarter of 2016.

117


PART II

ITEM 6. EXHIBITS
Exhibits filed herein are designated by an asterisk (*). All exhibits not so designated are incorporated by reference to a prior filing, as indicated. Items constituting management contracts or compensatory plans or arrangements are designated by a double asterisk (**). The Company agrees to furnish upon request to the Commission a copy of any omitted schedules or exhibits upon request on all items designated by a triple asterisk (***).
 
 
 
 
 
Duke
 
 
 
Duke
 
Duke
 
Duke
 
Duke
Exhibit
 
Duke
 
Energy
 
Progress
 
Energy
 
Energy
 
Energy
 
Energy
Number
 
Energy
 
Carolinas
 
Energy
 
Progress
 
Florida
 
Ohio
 
Indiana
4.1
Sixty-Eighth Supplemental Indenture, dated as of May 12, 2016 (incorporated by reference to Exhibit 4.1 to registrant's Current Report on Form 8-K filed on May 12, 2016, File No. 1-3543).
 
 
 
 
 
 
 
 
 
 
 
 
X
4.2
Forty-Fourth Supplemental Indenture, dated as of June 23, 2016 (incorporated by reference to Exhibit 4.1 registrant's Current Report on Form 8-K filed on June 23, 2016, File No. 1-1232).
 
 
 
 
 
 
 
 
 
 
X
 
 
*10.1
$1,500,000,000 Amended and Restated Term Loan Agreement among Duke Energy Corporation, as Borrower, the Lenders listed therein, The Bank of Tokyo-Mitsubishi UFJ, Ltd., as Administrative Agent, and The Bank of Tokyo-Mitsubishi UFJ, Ltd.,
Santander Bank, N.A. and TD Bank, N.A., as Joint Lead Arrangers and Bookrunners, dated as of August 1, 2016.
X
 
 
 
 
 
 
 
 
 
 
 
 
*12
Computation of Ratio of Earnings to Fixed Charges – DUKE ENERGY CORPORATION.
X
 
 
 
 
 
 
 
 
 
 
 
 
*31.1.1
Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
X
 
 
 
 
 
 
 
 
 
 
 
 
*31.1.2
Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
 
 
X
 
 
 
 
 
 
 
 
 
 
*31.1.3
Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
 
 
 
 
X
 
 
 
 
 
 
 
 
*31.1.4
Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
 
 
 
 
 
 
X
 
 
 
 
 
 
*31.1.5
Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
 
 
 
 
 
 
 
 
X
 
 
 
 
*31.1.6
Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
 
 
 
 
 
 
 
 
 
 
X
 
 
*31.1.7
Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
 
 
 
 
 
 
 
 
 
 
 
 
X
*31.2.1
Certification of the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
X
 
 
 
 
 
 
 
 
 
 
 
 
*31.2.2
Certification of the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
 
 
X
 
 
 
 
 
 
 
 
 
 
*31.2.3
Certification of the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
 
 
 
 
X
 
 
 
 
 
 
 
 
*31.2.4
Certification of the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
 
 
 
 
 
 
X
 
 
 
 
 
 
*31.2.5
Certification of the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
 
 
 
 
 
 
 
 
X
 
 
 
 
*31.2.6
Certification of the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
 
 
 
 
 
 
 
 
 
 
X
 
 
*31.2.7
Certification of the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
 
 
 
 
 
 
 
 
 
 
 
 
X

118


PART II

*32.1.1
Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
X
 
 
 
 
 
 
 
 
 
 
 
 
*32.1.2
Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
 
 
X
 
 
 
 
 
 
 
 
 
 
*32.1.3
Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
 
 
 
 
X
 
 
 
 
 
 
 
 
*32.1.4
Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
 
 
 
 
 
 
X
 
 
 
 
 
 
*32.1.5
Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
 
 
 
 
 
 
 
 
X
 
 
 
 
*32.1.6
Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
 
 
 
 
 
 
 
 
 
 
X
 
 
*32.1.7
Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
 
 
 
 
 
 
 
 
 
 
 
 
X
*32.2.1
Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
X
 
 
 
 
 
 
 
 
 
 
 
 
*32.2.2
Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
 
 
X
 
 
 
 
 
 
 
 
 
 
*32.2.3
Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
 
 
 
 
X
 
 
 
 
 
 
 
 
*32.2.4
Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
 
 
 
 
 
 
X
 
 
 
 
 
 
*32.2.5
Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
 
 
 
 
 
 
 
 
X
 
 
 
 
*32.2.6
Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
 
 
 
 
 
 
 
 
 
 
X
 
 
*32.2.7
Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
 
 
 
 
 
 
 
 
 
 
 
 
X
*101.INS
XBRL Instance Document.
X
 
X
 
X
 
X
 
X
 
X
 
X
*101.SCH
XBRL Taxonomy Extension Schema Document.
X
 
X
 
X
 
X
 
X
 
X
 
X
*101.CAL
XBRL Taxonomy Calculation Linkbase Document.
X
 
X
 
X
 
X
 
X
 
X
 
X
*101.LAB
XBRL Taxonomy Label Linkbase Document.
X
 
X
 
X
 
X
 
X
 
X
 
X
*101.PRE
XBRL Taxonomy Presentation Linkbase Document.
X
 
X
 
X
 
X
 
X
 
X
 
X
*101.DEF
XBRL Taxonomy Definition Linkbase Document.
X
 
X
 
X
 
X
 
X
 
X
 
X
The total amount of securities of the registrant or its subsidiaries authorized under any instrument with respect to long-term debt not filed as an exhibit does not exceed 10 percent of the total assets of the registrant and its subsidiaries on a consolidated basis. The registrant agrees, upon request of the SEC, to furnish copies of any or all of such instruments to it.

119


PART II

SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrants have duly caused this report to be signed on their behalf by the undersigned thereunto duly authorized.
 
 
DUKE ENERGY CORPORATION
DUKE ENERGY CAROLINAS, LLC
DUKE ENERGY PROGRESS, LLC
DUKE ENERGY FLORIDA, LLC
DUKE ENERGY OHIO, INC.
DUKE ENERGY INDIANA, LLC
 
 
 
Date:
August 4, 2016
/s/ STEVEN K. YOUNG
 
 
Steven K. Young
Executive Vice President and Chief Financial Officer (Principal Financial Officer)
 
 
 
Date:
August 4, 2016
/s/ WILLIAM E. CURRENS JR.
 
 
William E. Currens Jr.
Senior Vice President, Chief Accounting Officer
and Controller
(Principal Accounting Officer)
 
 
 
 
 
PROGRESS ENERGY, INC.
 
 
 
Date:
August 4, 2016
/s/ STEVEN K. YOUNG
 
 
Steven K. Young
Executive Vice President and Chief Financial Officer (Principal Financial Officer)
 
 
 
Date:
August 4, 2016
/s/ WILLIAM E. CURRENS JR.
 
 
William E. Currens Jr.
Chief Accounting Officer and Controller
(Principal Accounting Officer)

120