Edgar Filing: AES CORP

Large accelerated filer x

Accelerated filer ¨

Non-accelerated filer ¨

Smaller reporting company ¨

(Do not check if a smaller reporting company)

10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

______________________________________________________________________________________________

FORM 10-Q

(Mark One)



	x	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the Quarterly Period Ended March 31, 2016



	¨	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

Commission file number 1-12291

THE AES CORPORATION

(Exact name of registrant as specified in its charter)



Delaware		54 1163725
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification No.)
4300 Wilson Boulevard Arlington, Virginia		22203
(Address of principal executive offices)		(Zip Code)

(703) 522-1315

Registrant’s telephone number, including area code:

______________________________________________________________________________________________

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. Yes x No ¨

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, 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). 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. (Check one):

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ¨ No x

______________________________________________________________________________________________

The number of shares outstanding of Registrant’s Common Stock, par value $0.01 per share, on May 2, 2016 was 659,001,121

THE AES CORPORATION

FORM 10-Q

FOR THE QUARTERLY PERIOD ENDED MARCH 31, 2016

TABLE OF CONTENTS



Glossary of Terms		1

PART I: FINANCIAL INFORMATION		2

ITEM 1.	FINANCIAL STATEMENTS	2
	Condensed Consolidated Balance Sheets	2
	Condensed Consolidated Statements of Operations	3
	Condensed Consolidated Statements of Comprehensive Income (Loss)	4
	Condensed Consolidated Statements of Cash Flows	5
	Notes to Condensed Consolidated Financial Statements	6
	Note 1 - Financial Statement Presentation	6
	Note 2 - Inventory	7
	Note 3 - Fair Value	7
	Note 4 - Derivative Instruments and Hedging Activities	10
	Note 5 - Financing Receivables	11
	Note 6 - Investment in and Advances to Affiliates	11
	Note 7 - Debt	11
	Note 8 - Commitments and Contingencies	12
	Note 9 - Pension Plans	13
	Note 10 - Equity	14
	Note 11 - Segments	15
	Note 12 - Other Income and Expense	16
	Note 13 - Asset Impairment Expense	17
	Note 14 - Income Taxes	17
	Note 15 - Dispositions	17
	Note 16 - Acquisitions	17
	Note 17 - Earnings Per Share	17
	Note 18 - Subsequent Events	18

ITEM 2.	MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS	19

ITEM 3.	QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK	44

ITEM 4.	CONTROLS AND PROCEDURES	46

PART II: OTHER INFORMATION		47

ITEM 1.	LEGAL PROCEEDINGS	47

ITEM 1A.	RISK FACTORS	51

ITEM 2.	UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS	51

ITEM 3.	DEFAULTS UPON SENIOR SECURITIES	51

ITEM 4.	MINE SAFETY DISCLOSURES	51

ITEM 5.	OTHER INFORMATION	51

ITEM 6.	EXHIBITS	52

SIGNATURES		53

GLOSSARY OF TERMS

The following terms and acronyms appear in the text of this report and have the definitions indicated below:



Adjusted EPS	Adjusted Earnings Per Share, a non-GAAP measure
Adjusted PTC	Adjusted Pretax Contribution, a non-GAAP measure of operating performance
AES	The Parent Company and its subsidiaries and affiliates
AFS	Available For Sale
AFUDC	Allowance for Funds Used During Construction
ANEEL	Brazilian National Electric Energy Agency
AOCL	Accumulated Other Comprehensive Loss
ASC	Accounting Standards Codification
ASU	Accounting Standards Update
BNDES	Brazilian Development Bank
BoD	Board of Directors
CAA	United States Clean Air Act
CAMMESA	Wholesale Electric Market Administrator in Argentina
CCR	Coal Combustion Residuals
CDPQ	La Caisse de depot et placement du Quebec
CESCO	Central Electricity Supply Company of Orissa Ltd.
CFE	Federal Commission of Electricity
CO₂	Carbon Dioxide
CTA	Cumulative Translation Adjustment
DP&L	The Dayton Power & Light Company
DPL	DPL Inc.
DPLER	DPL Energy Resources, Inc.
EPA	United States Environmental Protection Agency
EPC	Engineering, Procurement and Construction
EURIBOR	Euro Interbank Offered Rate
FASB	Financial Accounting Standards Board
FCA	Federal Court of Appeals
FERC	Federal Energy Regulatory Commission
FX	Foreign Exchange
GAAP	Generally Accepted Accounting Principles in the United States
GHG	Greenhouse Gas
GSA	Gas Supply Agreement
GWh	Gigawatt Hours
ICC	International Chamber of Commerce
IPALCO	IPALCO Enterprises, Inc.
IPL	Indianapolis Power & Light Company
IURC	Indiana Utility Regulatory Commission
KPI	Key Performance Indicator
kWh	Kilowatt Hours
LIBOR	London Interbank Offered Rate
MATS	Mercury and Air Toxics Standards
MRE	Energy Reallocation Mechanism
MW	Megawatts
MWh	Megawatt Hours
NEK	Natsionalna Elektricheska Kompania (state-owned electricity public supplier in Bulgaria)
NOV	Notice of Violation
NO_X	Nitrogen Oxides
NCI	Noncontrolling Interest
OCI	Other Comprehensive Income
O&M	Operations and Maintenance
OPGC	Odisha Power Generation Corporation
Parent Company	The AES Corporation
PIS	Partially Integrated System
PPA	Power Purchase Agreement
PREPA	Puerto Rico Electric Power Authority
RSU	Restricted Stock Unit
RTO	Regional Transmission Organization
SIC	Central Interconnected Electricity System
SING	Northern Interconnected Electricity System
SBU	Strategic Business Unit
SEC	United States Securities and Exchange Commission
SO₂	Sulfur Dioxide
TA	Transportation Agreement
U.S.	United States
USD	United States Dollar
VAT	Value-Added Tax
VIE	Variable Interest Entity

PART I: FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

THE AES CORPORATION

Condensed Consolidated Balance Sheets

(Unaudited)



	March 31, 2016			December 31, 2015
	(in millions, except share and per share data)
ASSETS
CURRENT ASSETS
Cash and cash equivalents	$	1,185		$	1,262
Restricted cash	294			295
Short-term investments	628			484
Accounts receivable, net of allowance for doubtful accounts of $103 and $95, respectively	2,581			2,473
Inventory (see Note 2)	682			675
Prepaid expenses	116			108
Other current assets	1,461			1,449
Assets of held-for-sale businesses	—			96
Total current assets	6,947			6,842
NONCURRENT ASSETS
Property, Plant and Equipment:
Land	751			711
Electric generation, distribution assets and other	28,997			28,491
Accumulated depreciation	(9,768		)	(9,449		)
Construction in progress	3,436			3,063
Property, plant and equipment, net	23,416			22,816
Other Assets:
Investments in and advances to affiliates (see Note 6)	611			610
Debt service reserves and other deposits	415			565
Goodwill	1,157			1,157
Other intangible assets, net of accumulated amortization of $100 and $97, respectively	209			214
Deferred income taxes	599			543
Service concession assets, net of accumulated amortization of $52 and $34, respectively	1,505			1,543
Other noncurrent assets	2,041			2,180
Total other assets	6,537			6,812
TOTAL ASSETS	$	36,900		$	36,470
LIABILITIES AND EQUITY
CURRENT LIABILITIES
Accounts payable	$	1,739		$	1,721
Accrued interest	333			251
Accrued and other liabilities	2,280			2,436
Non-recourse debt, including $247 and $261, respectively, related to variable interest entities (see Note 7)	2,220			2,505
Liabilities of held-for-sale businesses	—			13
Total current liabilities	6,572			6,926
NONCURRENT LIABILITIES
Recourse debt (see Note 7)	4,924			4,966
Non-recourse debt, including $1,503 and $1,539, respectively, related to variable interest entities (see Note 7)	13,413			12,956
Deferred income taxes	1,118			1,090
Pension and other post-retirement liabilities (see Note 9)	985			927
Other noncurrent liabilities	3,032			2,896
Total noncurrent liabilities	23,472			22,835
Commitments and Contingencies (see Note 8)
Redeemable stock of subsidiaries	672			538
EQUITY (see Note 10)
THE AES CORPORATION STOCKHOLDERS’ EQUITY
Common stock ($0.01 par value, 1,200,000,000 shares authorized; 815,894,592 issued and 658,997,660 outstanding at March 31, 2016 and 815,846,621 issued and 666,808,790 outstanding at December 31, 2015)	8			8
Additional paid-in capital	8,706			8,718
Retained earnings	198			143
Accumulated other comprehensive loss	(3,807		)	(3,883		)
Treasury stock, at cost (156,896,932 shares at March 31, 2016 and 149,037,831 at December 31, 2015)	(1,904		)	(1,837		)
Total AES Corporation stockholders’ equity	3,201			3,149
NONCONTROLLING INTERESTS	2,983			3,022
Total equity	6,184			6,171
TOTAL LIABILITIES AND EQUITY	$	36,900		$	36,470

See Notes to Condensed Consolidated Financial Statements.

THE AES CORPORATION

Condensed Consolidated Statements of Operations

(Unaudited)



	Three Months Ended March 31,
	2016			2015
	(in millions, except per share amounts)
Revenue:
Regulated	$	1,776		$	2,080
Non-Regulated	1,695			1,904
Total revenue	3,471			3,984
Cost of Sales:
Regulated	(1,672		)	(1,807		)
Non-Regulated	(1,295		)	(1,456		)
Total cost of sales	(2,967		)	(3,263		)
Operating margin	504			721
General and administrative expenses	(48		)	(55		)
Interest expense	(364		)	(363		)
Interest income	130			90
Gain (loss) on extinguishment of debt	4			(23		)
Other expense	(8		)	(20		)
Other income	13			15
Gain on sale of businesses	47			1
Asset impairment expense	(159		)	(8		)
Foreign currency transaction gains (losses)	43			(23		)
Other non-operating expense	(2		)	—
INCOME FROM OPERATIONS BEFORE TAXES AND EQUITY IN EARNINGS OF AFFILIATES	160			335
Income tax expense	(92		)	(96		)
Net equity in earnings of affiliates	6			15
NET INCOME	74			254
Less: Net loss (income) attributable to noncontrolling interests	52			(112		)
NET INCOME ATTRIBUTABLE TO THE AES CORPORATION	$	126		$	142
BASIC EARNINGS PER SHARE:
NET INCOME ATTRIBUTABLE TO THE AES CORPORATION COMMON STOCKHOLDERS	$	0.19		$	0.20
DILUTED EARNINGS PER SHARE:
NET INCOME ATTRIBUTABLE TO THE AES CORPORATION COMMON STOCKHOLDERS	$	0.19		$	0.20
DILUTED SHARES OUTSTANDING	663			706
DIVIDENDS DECLARED PER COMMON SHARE	$	0.11		$	—

See Notes to Condensed Consolidated Financial Statements.

THE AES CORPORATION

Condensed Consolidated Statements of Comprehensive Income (Loss)

(Unaudited)



	Three Months Ended March 31,
	2016			2015
	(in millions)
NET INCOME	$	74		$	254
Foreign currency translation activity:
Foreign currency translation adjustments, net of $0 income tax for all periods	128			(421		)
Total foreign currency translation adjustments	128			(421		)
Derivative activity:
Change in derivative fair value, net of income tax benefit of $21 and $17, respectively	(64		)	(72		)
Reclassification to earnings, net of income tax benefit (expense) of $3 and $(2), respectively	(1		)	12
Total change in fair value of derivatives	(65		)	(60		)
Pension activity:
Change in pension adjustments due to prior service cost, net of $0 income tax for all periods	1			—
Change in pension adjustments due to net actuarial gain (loss) for the period, net of $0 income tax for all periods	(1		)	—
Reclassification to earnings due to amortization of net actuarial loss, net of income tax (expense) of $(1) and $(3), respectively	3			5
Total pension adjustments	3			5
OTHER COMPREHENSIVE INCOME (LOSS)	66			(476		)
COMPREHENSIVE INCOME (LOSS)	140			(222		)
Less: Comprehensive loss attributable to noncontrolling interests	62			88
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO THE AES CORPORATION	$	202		$	(134	)

See Notes to Condensed Consolidated Financial Statements.

THE AES CORPORATION

Condensed Consolidated Statements of Cash Flows

(Unaudited)



	Three Months Ended March 31,
	2016			2015
	(in millions)
OPERATING ACTIVITIES:
Net income	$	74		$	254
Adjustments to net income:
Depreciation and amortization	290			298
Gain on sale of businesses	(47		)	(1		)
Impairment expenses	161			8
Deferred income taxes	31			(12		)
(Reversals of) provisions for contingencies	(1		)	14
(Gain) loss on extinguishment of debt	(4		)	23
Other	(3		)	65
Changes in operating assets and liabilities
(Increase) decrease in accounts receivable	37			(337		)
(Increase) decrease in inventory	(24		)	(35		)
(Increase) decrease in prepaid expenses and other current assets	274			68
(Increase) decrease in other assets	(21		)	(290		)
Increase (decrease) in accounts payable and other current liabilities	(72		)	273
Increase (decrease) in income tax payables, net and other tax payables	(148		)	(15		)
Increase (decrease) in other liabilities	93			124
Net cash provided by operating activities	640			437
INVESTING ACTIVITIES:
Capital expenditures	(640		)	(619		)
Acquisitions, net of cash acquired	(6		)	(17		)
Proceeds from the sale of businesses, net of cash sold	115			—
Sale of short-term investments	1,603			1,076
Purchase of short-term investments	(1,708		)	(1,054		)
Decrease (increase) in restricted cash, debt service reserves and other assets	96			(75		)
Other investing	(8		)	(31		)
Net cash used in investing activities	(548		)	(720		)
FINANCING ACTIVITIES:
Borrowings under the revolving credit facilities	248			101
Repayments under the revolving credit facilities	(116		)	(62		)
Repayments of recourse debt	(116		)	(336		)
Issuance of non-recourse debt	161			574
Repayments of non-recourse debt	(248		)	(269		)
Payments for financing fees	(11		)	(9		)
Distributions to noncontrolling interests	(78		)	(19		)
Contributions from noncontrolling interests	28			67
Proceeds from the sale of redeemable stock of subsidiaries	134			247
Dividends paid on AES common stock	(73		)	(70		)
Payments for financed capital expenditures	(10		)	(42		)
Purchase of treasury stock	(79		)	(35		)
Other financing	(20		)	(34		)
Net cash (used in) provided by financing activities	(180		)	113
Effect of exchange rate changes on cash	7			(27		)
Increase (decrease) in cash of held-for-sale businesses	4			(5		)
Total decrease in cash and cash equivalents	(77		)	(202		)
Cash and cash equivalents, beginning	1,262			1,539
Cash and cash equivalents, ending	$	1,185		$	1,337
SUPPLEMENTAL DISCLOSURES:
Cash payments for interest, net of amounts capitalized	$	228		$	242
Cash payments for income taxes, net of refunds	$	182		$	103
SCHEDULE OF NONCASH INVESTING AND FINANCING ACTIVITIES:
Assets acquired through capital lease and other liabilities	$	3		$	5
Dividends declared but not yet paid	$	75		$	—

See Notes to Condensed Consolidated Financial Statements.

THE AES CORPORATION

Notes to Condensed Consolidated Financial Statements

For the Three Months Ended March 31, 2016 and 2015

1. FINANCIAL STATEMENT PRESENTATION

Consolidation

In this Quarterly Report the terms “AES,” “the Company,” “us” or “we” refer to the consolidated entity including its subsidiaries and affiliates. The terms “The AES Corporation,” “the Parent” or “the Parent Company” refer only to the publicly held holding company, The AES Corporation, excluding its subsidiaries and affiliates. Furthermore, variable interest entities (“VIEs”) in which the Company has a variable interest have been consolidated where the Company is the primary beneficiary. Investments in which the Company has the ability to exercise significant influence, but not control, are accounted for using the equity method of accounting. All intercompany transactions and balances have been eliminated in consolidation.

Interim Financial Presentation

The accompanying unaudited condensed consolidated financial statements and footnotes have been prepared in accordance with GAAP, as contained in the FASB ASC, for interim financial information and Article 10 of Regulation S-X issued by the SEC. Accordingly, they do not include all the information and footnotes required by GAAP for annual fiscal reporting periods. In the opinion of management, the interim financial information includes all adjustments of a normal recurring nature necessary for a fair presentation of the results of operations, financial position, comprehensive income and cash flows. The results of operations for the three months ended March 31, 2016 are not necessarily indicative of results that may be expected for the year ending December 31, 2016. The accompanying condensed consolidated financial statements are unaudited and should be read in conjunction with the 2015 audited consolidated financial statements and notes thereto, which are included in the 2015 Form 10-K filed with the SEC on February 23, 2016 (the “2015 Form 10-K”).

New Accounting Pronouncements

The following table provides a brief description of recent accounting pronouncements that had and/or could have a material impact on the Company’s consolidated financial statements:



New Accounting Standards Adopted
ASU Number and Name	Description	Date of Adoption	Effect on the financial statements upon adoption
2015-03, Interest — Imputation of Interest (Subtopic 835-30)	The standard simplifies the presentation of debt issuance costs by requiring that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. The recognition and measurement guidance for debt issuance costs are not affected by the standard. Transition method: retrospective.	January 1, 2016	Deferred financing costs of $24 million previously classified within other current assets and $357 million previously classified within other noncurrent assets were reclassified to reduce the related debt liabilities as of December 31, 2015.
2015-15, Interest — Imputation of Interest (Subtopic 835-30): Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements	Given the absence of authoritative guidance within ASU 2015-03, this standard clarifies that the SEC Staff would not object to an entity presenting debt issuance costs related to line-of-credit arrangements as an asset that is subsequently amortized ratably over the term of the line-of-credit arrangement, regardless of whether there are any outstanding borrowings on the line-of-credit arrangement. Transition method: retrospective.	January 1, 2016	Deferred financing costs related to lines-of-credit of $1 million recorded within other current assets and $23 million recorded within other noncurrent assets were not reclassified as of December 31, 2015.
2015-02, Consolidation — Amendments to the Consolidation Analysis (Topic 810)	The standard makes targeted amendments to the current consolidation guidance and ends the deferral granted to investment companies from applying the VIE guidance. The standard amends the evaluation of whether (1) fees paid to a decision-maker or service providers represent a variable interest, (2) a limited partnership or similar entity has the characteristics of a VIE and (3) a reporting entity is the primary beneficiary of a VIE. Transition method: retrospective.	January 1, 2016	None, other than that some entities previously consolidated under the voting model are now consolidated under the VIE model.
New Accounting Standards Issued But Not Yet Effective
ASU Number and Name	Description	Date of Adoption	Effect on the financial statements upon adoption
2016-09, Compensation — Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting	The standard simplifies the following aspects of accounting for share-based payments awards: accounting for income taxes, classification of excess tax benefits on the statement of cash flows, forfeitures, statutory tax withholding requirements, classification of awards as either equity or liabilities and classification of employee taxes paid on statement of cash flows when an employer withholds shares for tax-withholding purposes. Transition method: Various.	January 1, 2017. Early adoption is permitted.	The Company is currently evaluating the impact of adopting the standard on its consolidated financial statements.



2016-06, Derivatives and Hedging (Topic 815) — Contingent Put and Call Options in Debt Instruments	This standard clarifies the requirements for assessing whether contingent call (put) options that can accelerate the payment of principal on debt instruments are clearly and closely related to their debt hosts. When a call (put) option is contingently exercisable, an entity will no longer assess whether the event that triggers the ability to exercise a call (put) option is related to interest rates or credit risks. Transition method: a modified retrospective basis to existing debt instruments as of the effective date.	January 1, 2017. Early adoption is permitted.	The Company is currently evaluating the impact of adopting the standard, but does not anticipate a material impact on its consolidated financial statements.
2016-05, Derivatives and Hedging (Topic 815) — Effect of Derivative Contract Novations on Existing Hedge Accounting Relationships	The standard clarifies that a change in the counterparty to a derivative instrument that has been designated as the hedging instrument under Topic 815 does not require de-designation of that hedging relationship provided that all other hedge accounting criteria (including those in paragraphs 815-20-35-14 through 35-18) continue to be met. Transition method: prospective or a modified retrospective basis.	January 1, 2017. Early adoption is permitted.	The Company is currently evaluating the impact of adopting the standard, but does not anticipate a material impact on its consolidated financial statements.
2016-02, Leases (Topic 842)	The standard creates Topic 842, Leases which supersedes Topic 840, Leases, and introduces a lessee model that brings substantially all leases onto the balance sheet while retaining most of the principles of the existing lessor model in U.S. GAAP and aligning many of those principles with ASC 606, Revenue from Contracts with Customers. Transition method: modified retrospective approach with certain practical expedients.	January 1, 2019. Early adoption is permitted.	The Company is currently evaluating the impact of adopting the standard on its consolidated financial statements.
2016-01, Financial Instruments — Overall (Topic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities	The standard significantly revises an entity’s accounting related to (1) the classification and measurement of investments in equity securities and (2) the presentation of certain fair value changes for financial liabilities measured at fair value. Also, it amends certain disclosure requirements associated with the fair value of financial instruments. Transition: cumulative effect in Retained Earnings as of adoption or prospectively for equity investments without readily determinable fair value.	January 1, 2018. Limited early adoption permitted.	The Company is currently evaluating the impact of adopting the standard, but does not anticipate a material impact on its consolidated financial statements.
2015-11, Inventory (Topic 330): Simplifying the Measurement of Inventory	The standard replaces the current lower of cost or market test with a lower of cost or net realizable value test. Transition method: prospectively.	January 1, 2017. Early adoption is permitted.	The Company is currently evaluating the impact of adopting the standard on its consolidated financial statements.
2014-09, Revenue from Contracts with Customers (Topic 606)	The standard provides a single and comprehensive revenue recognition model for all contracts with customers to improve comparability. The revenue standard contains principles that an entity will apply to determine the measurement of revenue and timing of when it is recognized. The standard requires an entity to recognize revenue to depict the transfer of goods or services to customers at an amount that the entity expects to be entitled to in exchange for those goods or services. Transition method: a full retrospective or modified retrospective approach.	January 1, 2018 (as deferred by ASU No. 2015-14). Earlier application is permitted only as of January 1, 2017.	The Company is currently evaluating the impact of adopting the standard on its consolidated financial statements.
2016-08, Revenue from Contracts with Customers (Topic 606) — Principal versus Agent Considerations (Reporting Revenue Gross versus Net)	The standard clarifies how an entity should identify the unit of accounting for the principal versus agent evaluation and apply the control principle to certain types of arrangements. The amendments also re-frame the indicators to focus on evidence that an entity is acting as a principal rather than as an agent, revise existing examples and add new ones. Transition method: a full retrospective or modified retrospective approach.	January 1, 2018 (as deferred by ASU No. 2015-14). Earlier application is permitted only as of January 1, 2017.	The Company is currently evaluating the impact of adopting the standard on its consolidated financial statements.
2016-10, Revenue from Contracts with Customers (Topic 606): Identifying Performance Obligations and Licensing	This standard clarifies the following two aspects of Topic 606: identifying performance obligations and the licensing implementation guidance, while retaining the related principles for those areas. This standard reduces the cost and complexity of applying Topic 606 to the identification of promised goods or services, and it also includes implementation guidance on licensing. Transition method: a full retrospective or modified retrospective approach.	January 1, 2018 (as deferred by ASU No. 2015-14). Earlier application is permitted only as of January 1, 2017.	The Company is currently evaluating the impact of adopting the standard on its consolidated financial statements.

2. INVENTORY

The following table summarizes the Company’s inventory balances as of the periods indicated (in millions):



	March 31, 2016		December 31, 2015
Fuel and other raw materials	$	354	$	343
Spare parts and supplies	328		332
Total	$	682	$	675

3. FAIR VALUE

The fair value of current financial assets and liabilities, debt service reserves and other deposits approximate their reported carrying amounts. The estimated fair value of the Company’s assets and liabilities has been determined using available market information. By virtue of these amounts being estimates and based on hypothetical transactions to sell assets or transfer liabilities, the use of different market assumptions and/or estimation methodologies may have a material effect on the estimated fair value amounts. The Company made no

changes during the period to the fair valuation techniques described in Note 4.—Fair Value in Item 8.—Financial Statements and Supplementary Data of its 2015 Form 10-K.

Recurring Measurements — The following table presents by level within the fair value hierarchy, the Company’s financial assets and liabilities that were measured at fair value on a recurring basis as of the periods indicated (in millions). For the Company’s investments in marketable debt and equity securities, the security classes presented are determined based on the nature and risk of a security and are consistent with how the Company manages, monitors and measures its marketable securities:



	March 31, 2016								December 31, 2015
	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Assets
AVAILABLE FOR SALE:⁽¹⁾
Debt securities:
Unsecured debentures	$	—	$	568	$	—	$	568	$	—	$	327	$	—	$	327
Certificates of deposit	—		37		—		37		—		135		—		135
Government debt securities	—		11		—		11		—		28		—		28
Subtotal	—		616		—		616		—		490		—		490
Equity securities:
Mutual funds	—		15		—		15		—		15		—		15
Subtotal	—		15		—		15		—		15		—		15
Total available for sale	—		631		—		631		—		505		—		505
TRADING:
Equity securities:
Mutual funds	14		—		—		14		15		—		—		15
Total trading	14		—		—		14		15		—		—		15
DERIVATIVES:
Foreign currency derivatives	—		37		304		341		—		35		292		327
Commodity derivatives	—		67		4		71		—		41		7		48
Total derivatives	—		104		308		412		—		76		299		375
TOTAL ASSETS	$	14	$	735	$	308	$	1,057	$	15	$	581	$	299	$	895
Liabilities
DERIVATIVES:
Interest rate derivatives	$	—	$	48	$	416	$	464	$	—	$	54	$	304	$	358
Cross-currency derivatives	—		33		—		33		—		43		—		43
Foreign currency derivatives	—		46		14		60		—		41		15		56
Commodity derivatives	—		46		4		50		—		29		4		33
Total derivatives	—		173		434		607		—		167		323		490
TOTAL LIABILITIES	$	—	$	173	$	434	$	607	$	—	$	167	$	323	$	490

_____________________________


⁽¹⁾	Amortized cost approximated fair value at March 31, 2016 and December 31, 2015.

As of March 31, 2016, $605 million of AFS debt securities had stated maturities within one year and $11 million had stated maturities between 1 and 1.5 years. Gains and losses on the sale of investments are determined using the specific-identification method. For the three months ended March 31, 2016 and 2015, pretax realized gains and losses related to AFS and trading securities were less than $1 million, there was approximately $1 million in unrealized losses on AFS securities, and no other-than-temporary impairments of marketable securities were recognized in earnings or OCI. The table below presents the gross proceeds from sale of AFS securities for the periods indicated (in millions):



	Three Months Ended March 31,
	2016		2015
Gross proceeds from sale of AFS securities	$	1,619	$	1,086

The following tables present a reconciliation of net derivative assets and liabilities measured at fair value on a recurring basis using significant unobservable inputs (Level 3) for the three months ended March 31, 2016 and 2015 (presented in millions and net by type of derivative). Transfers between Level 3 and Level 2 are determined as of the end of the reporting period and principally result from changes in the significance of unobservable inputs used to calculate the credit valuation adjustment.



Three Months Ended March 31, 2016	Interest Rate			Foreign Currency			Commodity			Total
Balance at the beginning of the period	$	(304	)	$	277		$	3		$	(24	)
Total gains (losses) (realized and unrealized):
Included in earnings	3			47			—			50
Included in other comprehensive income — derivative activity	(99		)	3			—			(96		)
Included in other comprehensive income — foreign currency translation activity	(3		)	(33		)	—			(36		)
Settlements	18			(1		)	(3		)	14
Transfers of assets (liabilities) into Level 3	(31		)	—			—			(31		)
Transfers of (assets) liabilities out of Level 3	—			(3		)	—			(3		)
Balance at the end of the period	$	(416	)	$	290		$	—		$	(126	)
Total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets and liabilities held at the end of the period	$	4		$	45		$	—		$	49



Three Months Ended March 31, 2015	Interest Rate			Foreign Currency			Commodity			Cross Currency			Total
Balance at the beginning of the period	$	(210	)	$	209		$	6		$	—		$	5
Total gains (losses) (realized and unrealized):
Included in earnings	—			22			3			—			25
Included in other comprehensive income — derivative activity	(35		)	—			—			—			(35		)
Included in other comprehensive income — foreign currency translation activity	11			(6		)	—			—			5
Settlements	6			(2		)	(5		)	—			(1		)
Transfers of assets (liabilities) into Level 3	(74		)	—			—			(33		)	(107		)
Balance at the end of the period	$	(302	)	$	223		$	4		$	(33	)	$	(108	)
Total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets and liabilities held at the end of the period	$	—		$	21		$	3		$	—		$	24

The table below summarizes the significant unobservable inputs used for Level 3 derivative assets (liabilities) as of March 31, 2016 ($ in millions):



Type of Derivative	Fair Value			Unobservable Input	Amount or Range (Weighted Avg)
Interest rate	$	(416	)	Subsidiaries’ credit spreads	2.88% — 9.7% (5.65%)
Foreign currency:
Argentine Peso	304			Argentine Peso to USD currency exchange rate after one year	18.91 — 37.07 (27.78)
Other	(14		)
Total	$	(126	)

Nonrecurring Measurements

When evaluating impairment of long-lived assets and equity method investments, the Company measures fair value using the applicable fair value measurement guidance. Impairment expense is measured by comparing the fair value at the evaluation date to its then-latest available carrying amount. The following table summarizes major categories of assets and liabilities measured at fair value on a nonrecurring basis and their level within the fair value hierarchy (in millions):



Three Months Ended March 31, 2016	Measurement Date	Carrying Amount ⁽¹⁾		Fair Value						Pretax Loss
Assets	Measurement Date	Carrying Amount ⁽¹⁾		Level 1		Level 2		Level 3		Pretax Loss
Long-lived assets held and used: ⁽²⁾
Buffalo Gap II	03/31/2016	$	251	$	—	$	—	$	92	$	159



Three Months Ended March 31, 2015	Measurement Date	Carrying Amount ⁽¹⁾		Fair Value						Pretax Loss
Assets	Measurement Date	Carrying Amount ⁽¹⁾		Level 1		Level 2		Level 3		Pretax Loss
Long-lived assets held and used:
Other	Various	$	29	$	—	$	21	$	—	$	8
Equity method investments:
Solar Spain	02/09/2015	29		—		—		29		—

_____________________________


⁽¹⁾	Represents the carrying values at the dates of measurement, before fair value adjustment.


⁽²⁾	See Note 13—Asset Impairment Expense for further information.

The following table summarizes the significant unobservable inputs used in the Level 3 measurement on a nonrecurring basis during the three months ended March 31, 2016 ($ in millions):



	Fair Value		Valuation Technique	Unobservable Input	Range (Weighted Average)
Long-lived assets held and used:
Buffalo Gap II	$	92	Discounted cash flow	Annual revenue growth	-17% to 21% (20%)
				Annual pretax operating margin	-166% to 48% (18%)
				Weighted-average cost of capital	9	%

Financial Instruments not Measured at Fair Value in the Condensed Consolidated Balance Sheets

The next table presents (in millions) the carrying amount, fair value and fair value hierarchy of the Company’s financial assets and liabilities that are not measured at fair value in the Condensed Consolidated Balance Sheets as

of March 31, 2016 and December 31, 2015, but for which fair value is disclosed:



		March 31, 2016										December 31, 2015
		Carrying Amount		Fair Value								Carrying Amount		Fair Value
		Carrying Amount		Total		Level 1		Level 2		Level 3		Carrying Amount		Total		Level 1		Level 2		Level 3
Assets:	Accounts receivable — noncurrent⁽¹⁾	$	258	$	337	$	—	$	—	$	337	$	270	$	342	$	—	$	20	$	322
Liabilities:	Non-recourse debt	15,633		16,064		—		13,654		2,410		15,461		15,939		—		13,672		2,267
	Recourse debt	4,924		4,998		—		4,998		—		4,966		4,696		—		4,696		—

_____________________________


⁽¹⁾	These amounts principally relate to amounts due from CAMMESA, and are included in Noncurrent assets—Other in the accompanying Condensed Consolidated Balance Sheets. The fair value and carrying amount of these receivables exclude VAT of $24 million and $27 million as of March 31, 2016 and December 31, 2015, respectively.

4. DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES

There are no changes to the information disclosed in Note 1—General and Summary of Significant Accounting Policies—Derivatives and Hedging Activities of Item 8.—Financial Statements and Supplementary Data in the 2015 Form 10-K.

Volume of Activity — The following table presents the Company’s outstanding notional (in millions) under its types of derivatives as of March 31, 2016 with significant notionals, regardless of whether they are in qualifying cash flow hedging relationships, and the date through which the maturities for each type of derivative range:



Derivatives	Current Notional Translated to USD		Latest Maturity
Interest Rate (LIBOR and EURIBOR)	$	3,201	2033
Cross-Currency Swaps (Chilean Unidad de Fomento)	169		2028
Foreign Currency:
Argentine Peso	162		2026
Chilean Unidad de Fomento	304		2019
Others, primarily with weighted average remaining maturities of a year or less	687		2017

Accounting and Reporting — Assets and Liabilities — The following tables present amounts about assets and liabilities related to the Company’s derivative instruments as of March 31, 2016 and December 31, 2015 (in millions):



Fair Value	March 31, 2016						December 31, 2015
Assets	Designated		Not Designated		Total		Designated		Not Designated		Total
Foreign currency derivatives	$	14	$	327	$	341	$	8	$	319	$	327
Commodity derivatives	37		34		71		30		18		48
Total assets	$	51	$	361	$	412	$	38	$	337	$	375
Liabilities
Interest rate derivatives	$	464	$	—	$	464	$	358	$	—	$	358
Cross-currency derivatives	33		—		33		43		—		43
Foreign currency derivatives	35		25		60		35		21		56
Commodity derivatives	11		39		50		12		21		33
Total liabilities	$	543	$	64	$	607	$	448	$	42	$	490



	March 31, 2016				December 31, 2015
Fair Value	Assets		Liabilities		Assets		Liabilities
Current	$	92	$	145	$	86	$	144
Noncurrent	320		462		289		346
Total	$	412	$	607	$	375	$	490

Credit Risk-Related Contingent Features					March 31, 2016		December 31, 2015
Present value of liabilities subject to collateralization based on credit rating of certain subsidiaries					$	68	$	58
Cash collateral held by third parties or in an escrow account as a result of the credit rating					$	40	$	38

Earnings and Other Comprehensive (Loss) Income — The next table presents (in millions) the pretax gains (losses) recognized in AOCL and earnings related to all derivative instruments for the periods indicated:



	Three Months Ended March 31,
	2016			2015
Effective portion of cash flow hedges:
Gain (Losses) recognized in AOCL
Interest rate derivatives	$	(130	)	$	(98	)
Cross-currency derivatives	8			—
Foreign currency derivatives	—			2
Commodity derivatives	37			7
Total	$	(85	)	$	(89	)
Gain (Losses) reclassified from AOCL into earnings
Interest rate derivatives	$	(29	)	$	(24	)
Cross-currency derivatives	9			(1		)
Foreign currency derivatives	2			6
Commodity derivatives	22			5
Total	$	4		$	(14	)
Gain (Losses) recognized in earnings related to
Ineffective portion of cash flow hedges	$	2		$	(2	)
Not designated as hedging instruments:
Foreign currency derivatives	$	40		$	32
Other	(9		)	(8		)
Total	$	31		$	24

				Twelve Months Ended March 31, 2017
AOCL expected to increase (decrease) pre-tax income from continuing operations (primarily interest rate derivatives)				$	(104	)

5. FINANCING RECEIVABLES

Financing receivables are defined as receivables that have contractual maturities of greater than one year. The Company primarily has financing receivables pursuant to amended agreements or government resolutions that are due from certain governmental bodies in Argentina. Presented below are financing receivables by country as of the periods indicated (in millions):



	March 31, 2016		December 31, 2015
Argentina	$	219	$	237
United States	21		20
Brazil	42		39
Total long-term financing receivables	$	282	$	296

Argentina — Collection of the principal and interest on these receivables is subject to various business risks and uncertainties including, but not limited to, the completion and operation of power plants which generate cash for payments of these receivables, regulatory changes that could impact the timing and amount of collections, and economic conditions in Argentina. The Company monitors these risks including the credit ratings of the Argentine government on a quarterly basis to assess the collectability of these receivables. The Company accrues interest on these receivables once the recognition criteria have been met. The Company’s collection estimates are based on assumptions that it believes to be reasonable, but are inherently uncertain. Actual future cash flows could differ from these estimates.

6. INVESTMENTS IN AND ADVANCES TO AFFILIATES

Summarized Financial Information — The following table summarizes financial information of the Company’s 50%-or-less-owned affiliates that are accounted for using the equity method (in millions):



	Three Months Ended March 31,
50%-or-less-Owned Affiliates	2016		2015
Revenue	$	134	$	184
Operating margin	35		56
Net income	15		36

7. DEBT

Recourse Debt

During the first quarter of 2016, the Parent Company redeemed $125 million of its senior unsecured notes outstanding. The repayment included a portion of the 7.375% senior notes due in 2021, the 4.875% senior notes due in 2023, the 5.5% senior notes due in 2024, the 5.5% senior notes due in 2025 and the floating rate senior

notes due in 2019.

As a result of these transactions, the Company recognized a net gain on extinguishment of debt of $7 million that is included in the Condensed Consolidated Statement of Operations.

In March 2015, the Company redeemed in full the $151 million balance of its 7.75% senior unsecured notes due October 2015 and the $164 million balance of its 9.75% senior unsecured notes due April 2016. As a result of these transactions, the Company recognized a loss on extinguishment of debt of $23 million for the three months ended March 31, 2015 that is included in the Condensed Consolidated Statement of Operations.

Non-Recourse Debt

During the three months ended March 31, 2016, the Company’s subsidiaries engaged in the following significant debt transactions:



Subsidiary	Issuances		Repayments		Gain (Loss) on Extinguishment of Debt
IPALCO	$	148	$	83	$	—
Other	161		259		(2		)
	$	309	$	342	$	(2	)

Non-recourse Debt in default — The following table summarizes the Company’s subsidiary non-recourse debt in default as of March 31, 2016 (in millions). Due to the defaults, these amounts are included in the current portion of non-recourse debt:



Subsidiary	Primary Nature of Default	Debt in Default		Net Assets
Maritza (Bulgaria)⁽¹⁾	Covenant	$	551	$	719
Kavarna (Bulgaria)	Covenant	138		83
Sogrinsk (Kazakhstan)	Covenant	6		8
		$	695

_____________________________

⁽¹⁾ See Note 18—Subsequent Events for updates after March 31, 2016 impacting Maritza’s debt in default.

The above defaults are not payment defaults. All of the subsidiary non-recourse debt defaults were triggered by failure to comply with covenants and/or other conditions such as (but not limited to) failure to meet information covenants, complete construction or other milestones in an allocated time, meet certain minimum or maximum financial ratios, or other requirements contained in the non-recourse debt documents of the applicable subsidiary.

In the event that there is a default, bankruptcy or maturity acceleration at a subsidiary or group of subsidiaries that meets the applicable definition of materiality under the Parent Company’s corporate debt agreements, there could be a cross-default to the Company’s recourse debt. Materiality is defined in the Parent’s senior secured credit facility as having provided 20% or more of the total cash distributions from businesses to the Parent Company for the four most recently completed fiscal quarters. As of March 31, 2016, none of the defaults listed above individually or in the aggregate result in or are at risk of triggering a cross-default under the recourse debt of the Parent Company. In the event the Parent Company is not in compliance with the financial covenants of its senior secured credit facility, restricted payments will be limited to regular quarterly shareholder dividends at the then-prevailing rate. Payment and bankruptcy defaults would preclude the making of any restricted payments.

8. COMMITMENTS AND CONTINGENCIES

Guarantees, Letters of Credit and Commitments — In connection with certain project financing, acquisition, power purchase and other agreements, the Parent Company has expressly undertaken limited obligations and commitments, most of which will only be effective or will be terminated upon the occurrence of future events. In the normal course of business, the Parent Company has entered into various agreements, mainly guarantees and letters of credit, to provide financial or performance assurance to third parties on behalf of AES subsidiaries. These agreements are entered into primarily to support or enhance the creditworthiness otherwise achieved by a business on a stand-alone basis, thereby facilitating the availability of sufficient credit to accomplish their intended business purposes. Most of the contingent obligations relate to future performance commitments which the Company or its businesses expect to fulfill within the normal course of business. The expiration dates of these guarantees vary from less than one year to more than 19 years.

Presented below are the Parent Company’s current undiscounted exposure to guarantees and the range of maximum undiscounted potential exposure. The maximum exposure is not reduced by the amounts, if any, that could be recovered under the recourse or collateralization provisions in the guarantees. The table below summarizes the Parent Company’s contingent contractual obligations as of March 31, 2016 ($ in millions).



Contingent Contractual Obligations	Amount		No. of Agreements	Maximum Exposure Range for Each Agreement
Guarantees and commitments	$	355	13	<$1 — 53
Asset sale related indemnities ⁽¹⁾	27		1	$27
Cash collateralized letters of credit	31		3	$3 — 15
Letters of credit under the senior secured credit facility	62		9	<$1 — 29
Total	$	475	26

_____________________________


⁽¹⁾	Excludes normal and customary representations and warranties in agreements for the sale of assets (including ownership in associated legal entities) where the associated risk is considered to be nominal.

During the three months ended March 31, 2016, the Company paid letter of credit fees ranging from 0.2% to 2.5% per annum on the outstanding amounts of letters of credit.

Contingencies

Environmental — The Company periodically reviews its obligations as they relate to compliance with environmental laws, including site restoration and remediation. As of March 31, 2016 and December 31, 2015, the Company had recognized liabilities of $10 million for both periods, relating to projected environmental remediation costs. Due to the uncertainties associated with environmental assessment and remediation activities, future costs of compliance or remediation with current legislation or costs for new legislation introduced could be higher or lower than the amount currently accrued. Moreover, where no liability has been recognized, it is reasonably possible that the Company may be required to incur remediation costs or make expenditures in amounts that could be material but could not be estimated as of March 31, 2016. In aggregate, the Company estimates the potential losses related to environmental matters, where estimable, to be up to $1 million. The amounts considered reasonably possible do not include amounts accrued as discussed above.

Litigation — The Company is involved in certain claims, suits and legal proceedings in the normal course of business. The Company accrues for litigation and claims when it is probable that a liability has been incurred and the amount of loss can be reasonably estimated. The Company has evaluated claims in accordance with the accounting guidance for contingencies that it deems both probable and reasonably estimable and, accordingly, has recognized aggregate liabilities for all claims of approximately $234 million and $189 million as of March 31, 2016 and December 31, 2015, respectively. The increase in the current period is primarily related to the resolution of a dispute involving certain AES companies, for which the Company expects to be indemnified. Recognized aggregate liabilities for these claims are reported on the Condensed Consolidated Balance Sheets within Accrued and other liabilities and Other noncurrent liabilities. A significant portion of these accrued liabilities relate to labor and employment, non-income tax and customer disputes in international jurisdictions, principally Brazil where there are a number of labor and employment lawsuits. The complaints generally seek unspecified monetary damages, injunctive relief, or other relief. The AES subsidiaries have denied any liability and intend to vigorously defend themselves in all of these proceedings. There can be no assurance that these accrued liabilities will be adequate to cover all existing and future claims or that we will have the liquidity to pay such claims as they arise.

The Company believes, based upon information it currently possesses and taking into account established accruals for liabilities and its insurance coverage, that the ultimate outcome of these proceedings and actions is unlikely to have a material effect on the Company’s consolidated financial statements. However, where no accrued liability has been recognized, it is reasonably possible that some matters could be decided unfavorably to the Company and could require the Company to pay damages or make expenditures in amounts that could be material

but could not be estimated as of March 31, 2016. The material contingencies where a loss is reasonably possible primarily include (1) claims under financing agreements; (2) disputes with offtakers, suppliers and EPC contractors; (3) alleged violation of monopoly laws and regulations; (4) income tax and non-income tax matters with tax authorities; and (5) regulatory matters. In aggregate, the Company estimates that the range of potential losses, where estimable, related to these reasonably possible material contingencies is between $1.3 billion and $1.6 billion. Certain claims are in settlement negotiations. These claims considered reasonably possible do not include the amounts accrued, as discussed in the preceding paragraph, nor do they include income tax-related contingencies which are considered part of our uncertain tax positions.

Regulatory — During the fourth quarter of 2013, the Company recognized a regulatory liability of $269 million for a contingency related to an administrative ruling which required Eletropaulo to refund customers’ amounts related to the regulatory asset base. During the second half of 2014, Eletropaulo started refunding customers as part of the tariff. In January 2015, ANEEL updated the tariff to exclude any further customer refunds. On June 30, 2015, ANEEL included in the tariff reset the reimbursement to Eletropaulo of these amounts previously refunded to customers to begin in July 2015. During the second quarter of 2015, as a result of favorable events, management reassessed the contingency and determined that it no longer meets the recognition criteria under ASC 450 Contingencies. Management believes that it is now only reasonably possible that Eletropaulo will have to refund these amounts to customers. Accordingly, the Company reversed the remaining regulatory liability for this contingency of $161 million in the second quarter of 2015, which increased Regulated Revenue by $97 million and reduced Interest Expense by $64 million. Amounts related to this case are now included as part of our reasonably possible contingent range mentioned in the preceding paragraph.

9. PENSION PLANS

Total pension cost and employer contributions were as follows for the periods indicated (in millions):



	Three Months Ended March 31,
	2016						2015
	U.S.			Foreign			U.S.			Foreign
Service cost	$	3		$	3		$	4		$	4
Interest cost	10			81			12			102
Expected return on plan assets	(17		)	(52		)	(17		)	(72		)
Amortization of prior service cost	2			—			2			—
Amortization of net loss	5			4			5			8
Total pension cost	$	3		$	36		$	6		$	42

	Three Months Ended March 31, 2016						Remainder of 2016 (Expected)
	U.S.			Foreign			U.S.			Foreign
Total employer contributions	$	21		$	22		$	—		$	72

10. EQUITY

Changes in Equity — The table below is a reconciliation of the beginning and ending equity attributable to stockholders of The AES Corporation, noncontrolling interests (“NCI”) and total equity as of the periods indicated (in millions):



	Three Months Ended March 31, 2016									Three Months Ended March 31, 2015
	The Parent Stockholders’ Equity			NCI			Total Equity			The Parent Stockholders’ Equity			NCI			Total Equity
Balance at the beginning of the period	$	3,149		$	3,022		$	6,171		$	4,272		$	3,053		$	7,325
Net income (loss)	126			(52		)	74			142			112			254
Total foreign currency translation adjustment, net of income tax	100			28			128			(251		)	(170		)	(421		)
Total change in derivative fair value, net of income tax	(25		)	(40		)	(65		)	(26		)	(34		)	(60		)
Total pension adjustments, net of income tax	1			2			3			1			4			5
Cumulative effect of a change in accounting principle	—			—			—			(5		)	—			(5		)
Disposition of businesses	—			(2		)	(2		)	—			—			—
Distributions to noncontrolling interests	(2		)	(17		)	(19		)	—			(19		)	(19		)
Contributions from noncontrolling interests	—			28			28			—			67			67
Dividends declared on common stock	(71		)	—			(71		)	—			—			—
Purchase of treasury stock	(79		)	—			(79		)	(35		)	—			(35		)
Issuance and exercise of stock-based compensation benefit plans, net of income tax	4			—			4			5			—			5
Sale of subsidiary shares to noncontrolling interests	—			17			17			(81		)	—			(81		)
Acquisition of subsidiary shares from noncontrolling interests	(2		)	(3		)	(5		)	—			—			—
Balance at the end of the period	$	3,201		$	2,983		$	6,184		$	4,022		$	3,013		$	7,035

Equity Transactions with Noncontrolling Interests

IPALCO — In March 2016, La Caisse de depot et placement du Quebec (“CDPQ”) completed its investment commitment in IPALCO by investing $134 million in IPALCO Enterprises, Inc. (“IPALCO”). As a result of this transaction, IPALCO is owned by AES U.S. Investments (82.35%) and CDPQ (17.65%), and AES U.S. Investments is owned by AES U.S. Holdings, LLC (85%) and CDPQ (15%).

As a cumulative result of CDPQ’s investment transactions, the Company recognized an increase of $463 million to additional paid-in capital and a reduction to retained earnings of $463 million for the excess of the fair value of the shares over their book value. Additionally, $84 million in taxes and transaction costs were recognized as a net decrease to equity. Since the NCI is contingently redeemable, the total fair value of the consideration received of $594 million is classified in temporary equity as redeemable stock of subsidiaries on the Condensed Consolidated Balance Sheet as of March 31, 2016. No gain or loss was recognized in net income as the sale is not considered to be a sale of in-substance real estate. Any subsequent adjustments to allocate earnings and dividends to CDPQ will be classified as NCI within permanent equity and adjustments to the amount in temporary equity will occur only if and when it is probable that the shares will become redeemable. As the Company maintained control after the sale, IPALCO continues to be accounted for as a consolidated subsidiary within the US SBU reportable segment.

Jordan — On February 18, 2016, the Company completed the sale of 40% of its interest in a wholly owned subsidiary in Jordan which owns a controlling interest in the Jordan IPP4 gas-fired plant, for $21 million. The transaction was accounted for as a sale of in-substance real estate and a pretax gain of $4 million, net of transaction costs, was recognized in net income. The cash proceeds from the sale is reflected in Proceeds from the sale of businesses, net of cash sold on the Consolidated Statement of Cash Flows for the period ended March 31, 2016. After completion of the sale, the Company owns a 36% net ownership interest in Jordan IPP4 and will continue to manage and operate the plant, with 40% owned by Mitsui Ltd. and 24% owned by Nebras Power Q.S.C. As the Company maintained control after the sale, Jordan IPP4 continues to be consolidated by the Company within the Europe SBU reportable segment.

Accumulated Other Comprehensive Loss — See below for the changes in AOCL by component, net of tax and NCI, for the three months ended March 31, 2016 (in millions):



	Foreign currency translation adjustment, net			Unrealized derivative gains (losses), net			Unfunded pension obligations, net			Total
Balance at the beginning of the period	$	(3,256	)	$	(353	)	$	(274	)	$	(3,883	)
Other comprehensive income (loss) before reclassifications	100			(25		)	—			75
Amount reclassified to earnings	—			—			1			1
Other comprehensive income (loss)	100			(25		)	1			76
Balance at the end of the period	$	(3,156	)	$	(378	)	$	(273	)	$	(3,807	)

Reclassifications out of AOCL are presented in the following table. Amounts for the periods indicated are in millions and those in parenthesis indicate debits to the Condensed Consolidated Statements of Operations:



Details About		Three Months Ended March 31,
AOCL Components	Affected Line Item in the Condensed Consolidated Statements of Operations	2016			2015
Unrealized derivative gains (losses), net
	Non-regulated revenue	$	42		$	5
	Non-regulated cost of sales	(21		)	—
	Interest expense	(29		)	(25		)
	Foreign currency transaction gains (losses)	12			6
	Income from operations before taxes and equity in earnings of affiliates	4			(14		)
	Income tax expense	(3		)	2
	Net Income	1			(12		)
	Less: (Income) from operations attributable to noncontrolling interests	(1		)	3
	Net income attributable to The AES Corporation	$	—		$	(9	)
Amortization of defined benefit pension actuarial loss, net
	Regulated cost of sales	$	(4	)	$	(8	)
	Income from operations before taxes and equity in earnings of affiliates	(4		)	(8		)
	Income tax expense	1			3
	Net Income	(3		)	(5		)
	Less: (Income) from operations attributable to noncontrolling interests	2			4
	Net income attributable to The AES Corporation	$	(1	)	$	(1	)
Total reclassifications for the period, net of income tax and noncontrolling interests		$	(1	)	$	(10	)

Common Stock Dividends — The Company paid dividends of $0.11 per outstanding share to its common stockholders during the first quarter of 2016 for dividends declared in December 2015.

On February 19, 2016, the Company declared dividends of $0.11 per outstanding common share payable on May 16, 2016 to the shareholders of record at the close of business on May 2, 2016.

Stock Repurchase Program — During the three months ended March 31, 2016, the Parent Company repurchased 8.7 million shares of its common stock at a total cost of $79 million under the existing stock repurchase program (the “Program”). The cumulative repurchases from the commencement of the Program in July 2010 through March 31, 2016 totaled 154.3 million shares for a total cost of $1.9 billion, at an average price per share of $12.12 (including a nominal amount of commissions). As of March 31, 2016, $264 million remained available for repurchase under the Program.

11. SEGMENTS

The segment reporting structure uses the Company’s management reporting structure as its foundation to reflect how the Company manages the businesses internally and is organized by geographic regions which provide better socio-political-economic understanding of our business. The management reporting structure is organized by six SBUs led by our President and Chief Executive Officer: US; Andes; Brazil; MCAC; Europe; and Asia SBUs. Using the accounting guidance on segment reporting, the Company determined that it has six reportable segments corresponding to its six SBUs.

Corporate and Other — Corporate overhead costs which are not directly associated with the operations of our six reportable segments are included in “Corporate and Other.” Also included are certain intercompany charges such as self-insurance premiums which are fully eliminated in consolidation.

The Company uses Adjusted PTC as its primary segment performance measure. Adjusted PTC, a non-GAAP measure, is defined by the Company as pretax income from continuing operations attributable to AES excluding (1)unrealized gains or losses related to derivative transactions, (2) unrealized foreign currency gains or losses, (3)gains or losses due to dispositions and acquisitions of business interests, (4) losses due to impairments, and (5)costs due to the early retirement of debt. The Company has concluded that Adjusted PTC best reflects the underlying business performance of the Company and is the most relevant measure considered in the Company’s internal evaluation of the financial performance of its segments. Additionally, given its large number of businesses and complexity, the Company concluded that Adjusted PTC is a more transparent measure that better assists investors in determining which businesses have the greatest impact on the Company’s results.

Revenue and Adjusted PTC are presented before inter-segment eliminations, which includes the effect of intercompany transactions with other segments except for interest, charges for certain management fees, and the write-off of intercompany balances, as applicable. All intra-segment activity has been eliminated within the segment. Inter-segment activity has been eliminated within the total consolidated results.

The following tables present financial information by segment for the periods indicated (in millions):



	Total Revenue
Three Months Ended March 31,	2016			2015
US SBU	$	855		$	997
Andes SBU	622			612
Brazil SBU	1,040			1,330
MCAC SBU	519			598
Europe SBU	246			330
Asia SBU	194			119
Corporate and Other	1			4
Eliminations	$	(6	)	$	(6	)
Total Revenue	$	3,471		$	3,984



	Total Adjusted PTC
Three Months Ended March 31,	2016			2015
US SBU	$	85		$	106
Andes SBU	61			91
Brazil SBU	(9		)	21
MCAC SBU	48			50
Europe SBU	69			85
Asia SBU	22			12
Corporate and Other	(104		)	(113		)
Total Adjusted PTC	$	172		$	252
Reconciliation to Income from Continuing Operations before Taxes and Equity Earnings of Affiliates:
Non-GAAP Adjustments:
Unrealized derivative gains	34			15
Unrealized foreign currency gains (losses)	8			(47		)
Disposition/acquisition gains	19			5
Impairment losses	(50		)	(6		)
Loss on extinguishment of debt	(1		)	(27		)
Pretax contribution	182			192
Add: (Loss) Income from continuing operations before taxes attributable to noncontrolling interests	(16		)	158
Less: Net equity in earnings of affiliates	6			15
Income from continuing operations before taxes and equity in earnings of affiliates	$	160		$	335



Total Assets	March 31, 2016		December 31, 2015
US SBU	$	9,890	$	9,800
Andes SBU	8,484		8,594
Brazil SBU	6,988		6,419
MCAC SBU	4,921		4,820
Europe SBU	3,140		3,101
Asia SBU	3,135		3,099
Assets of held-for-sale businesses	—		96
Corporate and Other	342		541
Total Assets	$	36,900	$	36,470

12. OTHER INCOME AND EXPENSE

Other income generally includes gains on asset sales and liability extinguishments, favorable judgments on contingencies, and other income from miscellaneous transactions. Other expense generally includes losses on asset sales and dispositions, losses on legal contingencies and losses from other miscellaneous transactions. The components are summarized as follows (in millions):



		Three Months Ended March 31,
		2016		2015
Other Income	Allowance for funds used during construction (US utilities)	$	7	$	4
	Gain on sale of assets	2		5
	Other	4		6
	Total other income	$	13	$	15

Other Expense	Loss on sale and disposal of assets	$	7	$	15
	Legal settlement	1		3
	Other	—		2
	Total other expense	$	8	$	20

13. ASSET IMPAIRMENT EXPENSE



	Three Months Ended March 31,
(in millions)	2016		2015
Buffalo Gap II	$	159	$	—
Other	—		8
Total asset impairment expense	$	159	$	8

Buffalo Gap II — During the first quarter of 2016, the Company tested the recoverability of its long-lived assets at Buffalo Gap II. Impairment indicators were identified based on a decline in forward power curves. The Company determined that the carrying amount was not recoverable. The Buffalo Gap II asset group was determined to have a fair value of $92 million using the income approach. As a result, the Company recognized asset impairment expense of $159 million ($49 million attributable to AES). Buffalo Gap II is reported in the US SBU reportable segment.

14. INCOME TAXES

Chilean Tax Reform — In February 2016, the Chilean government enacted further reforms to its income tax laws that resulted in an increase to statutory income tax rates for most of our Chilean businesses from 25% to 25.5% in 2017 and to 27% for 2018 and future years. The impact of remeasuring deferred taxes to account for the enacted change in future applicable income tax rates was recognized as discrete income tax expense in the first quarter of 2016, resulting in an increase of $26 million to consolidated income tax expense.

15. DISPOSITIONS

DPLER — On January 1, 2016, the Company completed the sale of its interest in DPLER, a competitive retail marketer selling electricity to customers in Ohio. Upon completion, proceeds of $76 million were received and a gain on sale of $49 million was recognized. The sale of DPLER did not meet the criteria to be reported as a discontinued operation. Prior to its sale, DPLER was reported in the US SBU reportable segment.

Kelanitissa — On January 27, 2016, the Company completed the sale of its interest in Kelanitissa, a diesel-fired generation station in Sri Lanka. Upon completion, proceeds of $18 million were received and a loss on sale of $5 million was recognized. The sale of Kelanitissa did not meet the criteria to be reported as a discontinued operation. Prior to its sale, Kelanitissa was reported in the Asia SBU reportable segment.

16. ACQUISITIONS

Main Street Power — On February 18, 2015, the Company completed the acquisition of 100% of the common stock of Main Street Power Company, Inc. for approximately $25 million pursuant to the terms and condition of a definitive agreement dated January 24, 2015. The purchase consideration was composed of $20 million cash and the fair value of earn-out payments of $5 million. At December 31, 2015, the assets acquired (including $4 million cash) and liabilities assumed at the acquisition date were recorded at fair value based on the final purchase price allocation, which resulted in the recognition of $16 million of goodwill. Subsequent changes to the fair value of earn-out payments will be reflected in earnings. Since the date of acquisition, Main Street Power Company, Inc. has been renamed Distributed Energy, Inc.

17. EARNINGS PER SHARE

Basic and diluted earnings per share are based on the weighted average number of shares of common stock and potential common stock outstanding during the period. Potential common stock, for purposes of determining diluted earnings per share, includes the effects of dilutive RSUs, stock options and convertible securities. The effect of such potential common stock is computed using the treasury stock method or the if-converted method, as applicable. Presented below is a reconciliation, for the periods indicated, of the numerator and denominator of the basic and diluted earnings per share computation for income from continuing operations, where income represents the numerator and weighted average shares represents the denominator:



(in millions except per share data)	2016					2015
	Income		Shares	$ per Share		Income		Shares	$ per Share
Three Months Ended March 31,
BASIC EARNINGS PER SHARE
Income from continuing operations attributable to The AES Corporation common stockholders	$	126	661	$	0.19	$	142	704	$	0.20
EFFECT OF DILUTIVE SECURITIES
Restricted stock units	—		2	—		—		2	—
DILUTED EARNINGS PER SHARE	$	126	663	$	0.19	$	142	706	$	0.20

For the three months ended March 31, the calculation of diluted earnings per share excluded 8 million and 6 million outstanding stock awards for 2016 and 2015, respectively, that could potentially dilute basic earnings per share in the future. Additionally, for the three months ended March 31, 2016 and 2015, all 15 million shares of potential common stock associated with convertible debentures were omitted from the earnings per share calculation. These were not included because the impact would have been anti-dilutive.

18. SUBSEQUENT EVENTS

Bulgaria — In April 2016, Maritza received all overdue payments from NEK, totaling $291 million. In addition, all other conditions precedent were satisfied by NEK, which resulted in the extinguishment of $57 million of liabilities owed by Maritza to MMI, a Maritza fuel supplier. The remaining conditions precedent to cure Maritza’s debt covenant violation are administrative in nature and are generally within control of the Company; these conditions are expected to be satisfied in the second quarter of 2016, at which time we expect to reclassify $493 million of Maritza’s non-recourse debt from current to non-current. See Note 7—Debt for further information regarding non-recourse debt in default.

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

In this Quarterly Report on Form 10-Q (“Form 10-Q”), the terms “AES,” “the Company,” “us,” or “we” refer to the consolidated entity and all of its subsidiaries and affiliates, collectively. The term “The AES Corporation”, “the Parent Company”, or “the Parent” refers only to the parent, publicly held holding company, The AES Corporation, excluding its subsidiaries and affiliates. The condensed consolidated financial statements included in Item 1.—Financial Statements of this Form 10-Q and the discussions contained herein should be read in conjunction with our 2015 Form 10-K.

FORWARD-LOOKING INFORMATION

The following discussion may contain forward-looking statements regarding us, our business, prospects and our results of operations that are subject to certain risks and uncertainties posed by many factors and events that could cause our actual business, prospects and results of operations to differ materially from those that may be anticipated by such forward-looking statements. Factors that could cause or contribute to such differences include, but are not limited to, those described in Item 1A.—Risk Factors and Item 7.—Management’s Discussion and Analysis of Financial Condition and Results of Operations of our 2015 Form 10-K and subsequent filings with the SEC. Readers are cautioned not to place undue reliance on these forward-looking statements which speak only as of the date of this report. We undertake no obligation to revise any forward-looking statements in order to reflect events or circumstances that may subsequently arise. If we do update one or more forward-looking statements, no inference should be drawn that we will make additional updates with respect to those or other forward-looking statements. Readers are urged to carefully review and consider the various disclosures made by us in this report and in our other reports filed with the SEC that advise of the risks and factors that may affect our business.

Overview of Our Business — We are a diversified power generation and utility company organized into the following six market-oriented SBUs: US (United States); Andes (Chile, Colombia and Argentina); Brazil; MCAC (Mexico, Central America and the Caribbean); Europe (Europe and Middle East); and Asia (India, Philippines, Vietnam, and Sri Lanka). For additional information regarding our business, see Item 1.—Business of our 2015 Form 10-K.

Within our six SBUs listed above, we have two lines of business. The first business line is generation, where we own and/or operate power plants to generate and sell power to customers such as utilities, industrial users and other intermediaries. The second business line is utilities, where we own and/or operate utilities to generate or purchase, distribute, transmit and sell electricity to end-user customers in the residential, commercial, industrial and governmental sectors within a defined service area. In certain circumstances, our utilities also generate and sell electricity on the wholesale market.

Key Topics in Management’s Discussion and Analysis — Our discussion covers the following:


•	Overview of Q1 2016 Results and Strategic Performance


•	Review of Consolidated Results of Operations


•	Non-GAAP Measures and SBU Performance Analysis


•	Key Trends and Uncertainties


•	Capital Resources and Liquidity

Overview of Q1 2016 Results and Strategic Performance

Management’s Strategic Priorities — Management is focused on the following priorities:

•

Leveraging our platforms — We are focusing our growth on platform expansions in markets where we already operate and have a competitive advantage to realize attractive risk-adjusted returns. We currently have 5,945 MW under construction. These projects represent $7.5 billion in total capital expenditures, with the majority of AES’ $1.3 billion in equity already funded. We expect the majority of these projects to come on-line through 2018. Beyond the projects we currently have under construction, we will continue to advance select projects from our development pipeline.


•	Reducing complexity — By exiting businesses and markets where we do not have a competitive advantage, we are simplifying our portfolio and reducing risk. During the first quarter of 2016, we announced or closed $249 million in equity proceeds from the sales or sell-downs of four businesses.


•	Performance excellence — We strive to be the low-cost manager of a portfolio of assets and to derive synergies and scale from our businesses. In late 2015, we launched a $150 million cost reduction and revenue

enhancement initiative. This initiative will include overhead reductions, procurement efficiencies and operational improvements. We expect to achieve at least $50 million in savings in 2016, ramping up to a total of $150 million in 2018.

•

Expanding access to capital — We are building strategic partnerships at the project- and business-levels. Through these partnerships, we aim to optimize our risk-adjusted returns in our existing businesses and growth projects. By selling down portions of certain businesses, we can adjust our global exposure to commodity, fuel, country and other macroeconomic risks. Partial sell-downs of our assets can also serve to highlight or enhance the value of businesses in our portfolio.

•

Allocating capital in a disciplined manner — Our top priority is to maximize risk-adjusted returns to our shareholders, which we achieve by investing our discretionary cash and recycling the capital we receive from asset sales and strategic partnerships. In the first quarter of 2016, we generated substantial cash by executing on our strategy, which we allocated in line with our capital allocation framework:


◦	Used $116 million to prepay Parent debt;


◦	Returned $151 million to shareholders through share repurchases and quarterly dividends; and


◦	Invested $139 million in our subsidiaries.

Q1 2016 Strategic Performance

Earnings Per Share and Proportional Free Cash Flow Results in Q1 2016 (in millions, except per share amounts)



	Three Months Ended March 31,
	2016		2015		$ Change			% Change
Diluted earnings per share from continuing operations	$	0.19	$	0.20	$	(0.01	)	-5	%
Adjusted EPS (a non-GAAP measure) ⁽¹⁾	0.13		0.25		(0.12		)	-48	%
Net cash provided by operating activities	640		437		203			46	%
Proportional free cash flow (a non-GAAP measure) ⁽¹⁾	253		265		(12		)	-5	%

_____________________________


⁽¹⁾	See reconciliation and definition under Non-GAAP Measures.

Three Months Ended March 31, 2016

Diluted earnings per share from continuing operations decreased $0.01, or 5%, to $0.19, primarily due to lower operating margin; partially offset by unrealized foreign currency transaction gains, gains on extinguishment of debt, unrealized derivative gains, gain on sale of our interest in DPLER, and higher interest income.

Adjusted EPS, a non-GAAP measure, decreased $0.12, or 48%, to $0.13, primarily driven by a higher effective tax rate, and lower operating margin at Tietê, DPL and Eletropaulo; partially offset by lower share count, gain on contract termination at DP&L, and Mong Duong Unit 2 commencing operations in April 2015.

Net cash provided by operating activities increased by $203 million, or 46% to $640 million, primarily driven by an increase in collections at our Brazil utilities and a full quarter’s impact from the commencement of operations at Mong Duong. These favorable impacts were offset by lower operating margin and a decline in collections in the Dominican Republic and Puerto Rico.

Proportional free cash flow decreased by $12 million, or 5% to $253 million, primarily due to lower operating margin, a decline in collections in the Dominican Republic and Puerto Rico, and an increase in fuel supplier payments at Maritza. These impacts were partially offset by an increase in collections at our Brazil utilities and a full quarter’s impact from the commencement of operations at Mong Duong.

Safe Operations — Safety is our first value and a top priority. We consistently analyze and evaluate our safety performance in order to capture lessons learned and strengthen mitigation plans that improve our safety performance.

Review of Consolidated Results of Operations



	Three Months Ended March 31,
($ in millions, except per share amounts)	2016			2015			$ Change			% Change
Revenue:
US SBU	$	855		$	997		$	(142	)	-14	%
Andes SBU	622			612			10			2	%
Brazil SBU	1,040			1,330			(290		)	-22	%
MCAC SBU	519			598			(79		)	-13	%
Europe SBU	246			330			(84		)	-25	%
Asia SBU	194			119			75			63	%
Corporate and Other	1			4			(3		)	-75	%
Intersegment eliminations	(6		)	(6		)	—			—	%
Total Revenue	3,471			3,984			(513		)	-13	%
Operating Margin:
US SBU	114			173			(59		)	-34	%
Andes SBU	123			131			(8		)	-6	%
Brazil SBU	39			177			(138		)	-78	%
MCAC SBU	96			103			(7		)	-7	%
Europe SBU	83			103			(20		)	-19	%
Asia SBU	37			24			13			54	%
Corporate and Other	8			12			(4		)	-33	%
Intersegment eliminations	4			(2		)	6			300	%
Total Operating Margin	504			721			(217		)	-30	%
General and administrative expenses	(48		)	(55		)	7			-13	%
Interest expense	(364		)	(363		)	(1		)	NM
Interest income	130			90			40			44	%
Gain (loss) on extinguishment of debt	4			(23		)	27			117	%
Other expense	(8		)	(20		)	12			-60	%
Other income	13			15			(2		)	-13	%
Gain on sale of businesses	47			1			46			NM
Asset impairment expense	(159		)	(8		)	(151		)	NM
Foreign currency transaction gains (losses)	43			(23		)	66			287	%
Other non-operating expense	(2		)	—			(2		)	100	%
Income tax expense	(92		)	(96		)	4			-4	%
Net equity in earnings of affiliates	6			15			(9		)	-60	%
NET INCOME	74			254			(180		)	-71	%
Less: Net loss (income) attributable to noncontrolling interests	52			(112		)	164			-146	%
NET INCOME ATTRIBUTABLE TO THE AES CORPORATION	$	126		$	142		$	(16	)	-11	%
Net cash provided by operating activities	$	640		$	437		$	203		46	%
DIVIDENDS DECLARED PER COMMON SHARE	$	0.11		$	—		$	0.11		100	%

NM - Not Meaningful

Components of Revenue, Cost of Sales, Operating Margin, and Operating Cash Flow — Revenue includes revenue earned from the sale of energy from our utilities and the production of energy from our generation plants, which are classified as regulated and non-regulated, respectively, on the Condensed Consolidated Statements of Operations. Revenue also includes the gains or losses on derivatives associated with the sale of electricity.

Cost of sales includes costs incurred directly by the businesses in the ordinary course of business. Examples include electricity and fuel purchases, O&M costs, depreciation and amortization expense, bad debt expense and recoveries, general administrative and support costs (including employee-related costs directly associated with the operations of the business). Cost of sales also includes the gains or losses on derivatives (including embedded derivatives other than foreign currency embedded derivatives) associated with the purchase of electricity or fuel.

Operating margin is defined as revenue less cost of sales.

Consolidated Revenue and Operating Margin — Executive Summary

Three months ended March 31, 2016:

Consolidated Revenue — Revenue decreased $513 million, or 13%, to $3.5 billion in the three months ended

March 31, 2016, compared with $4.0 billion in the three months ended March 31, 2015. This decrease was driven primarily by unfavorable FX impacts of $468 million, primarily in Brazil of $378 million. Additionally, revenues were impacted in Brazil due to Uruguiana operating in the first quarter of 2015 but not in 2016 (primarily pass-through), and lower volumes and rates at Tietê. Revenues also declined due to the sale of DPLER in January 2016. These decreases were partially offset by the impact of full operations at Mong Duong being online throughout the first quarter of 2016, compared to only Unit 1 of Mong Duong coming online in March of 2015.

Consolidated Operating Margin — Operating margin decreased $217 million, or 30%, to $504 million in the three months ended March 31, 2016, compared with $721 million in the three months ended March 31, 2015. This decrease was driven primarily by lower contract and spot prices at Tietê in Brazil; the impact of lower wholesale prices and completion of DP&L’s required transition to market; and unfavorable FX impacts of $41 million, primarily in Kazakhstan ($12 million), Brazil ($10 million), and Argentina ($9 million).

See Item 2.—SBU Performance Analysis of this Form 10-Q for additional discussion and analysis of operating results for each SBU.

Consolidated Results of Operations — Other

General and administrative expenses

General and administrative expenses decreased $7 million, or 13%, to $48 million for the three months ended March 31, 2016, primarily due to decreased employee-related costs and business development costs.

Interest expense

Interest expense increased $1 million, or 0%, to $364 million for the three months ended March 31, 2016. The increase was primarily due to an increase at Mong Duong as a result of the plant being fully operational during the first quarter of 2016 which resulted in lower capitalized interest. This increase was partially offset by lower expense at the Parent Company and DPL due to a reduction in debt principal, and lower expense at IPALCO due to increased capitalized interest and lower rates.

Interest income

Interest income increased $40 million, or 44%, to $130 million for the three months ended March 31, 2016. The increase was primarily due to $26 million of income recognized on the financing element of the service concession arrangement at Mong Duong, which was fully operational for the first quarter of 2016, whereas only one unit was operational in March 2015; as well as an increase of $14 million at Eletropaulo as a result of an increase in regulatory assets and higher interest rates.

Gain (loss) on extinguishment of debt

Gain (loss) on extinguishment of debt was $4 million for the three months ended March 31, 2016, and $(23) million for the three months ended March 31, 2015, respectively. See Note 7—Debt in Item 1.—Financial Statements of this Form 10-Q for further information.

Other income and expense

Other income was $13 million for the three months ended March 31, 2016, and $15 million for the three months ended March 31, 2015. See Note 12—Other Income and Expense in Item 1.—Financial Statements of this Form 10-Q for further information.

Other expense was $8 million for the three months ended March 31, 2016, and $20 million for the three months ended March 31, 2015. See Note 12—Other Income and Expense in Item 1.—Financial Statements of this Form 10-Q for further information.

Gain on sale of businesses

Gain on sale of businesses was $47 million for the three months ended March 31, 2016, and $1 million for the three months ended March 31, 2015. See Note 10—Equity and Note 15—Dispositions in Item 1.—Financial Statements of this Form 10-Q for further information.

Asset impairment expense

Asset impairment expense was $159 million ($49 million attributable to AES) for the three months ended March 31, 2016, and $8 million for the three months ended March 31, 2015. See Note 13—Asset Impairment Expense in Item 1.—Financial Statements of this Form 10-Q for further information.

Foreign currency transaction gains (losses) — Activity was as follows (in millions):



	Three Months Ended March 31,
	2016		2015
Argentina	$	30	$	15
Parent Company	8		(33		)
Other	5		(5		)
Total ⁽¹⁾	$	43	$	(23	)

___________________________________________


⁽¹⁾	Includes $45 million and $36 million of gains on foreign currency derivative contracts for the three months ended March 31, 2016 and 2015, respectively.

The Company recognized net foreign currency transaction gains of $43 million for the three months ended March 31, 2016, primarily due to:


•	a gain of $30 million in Argentina, which was primarily related to the favorable impact of foreign currency derivatives associated with government receivables at AES Argentina.

The Company recognized foreign currency transaction losses of $23 million for the three months ended March 31, 2015, primarily due to:


•	a loss of $33 million at The Parent Company, which was primarily due to remeasurement losses on intercompany notes receivable, partially offset by gains on foreign currency options; and


•	a gain of $15 million in Argentina, which was primarily related to the favorable impact of foreign currency derivatives associated with government receivables at AES Argentina.

Income tax expense

Income tax expense decreased $4 million, or 4%, to $92 million for the three months ended March 31, 2016 compared to $96 million for the three months ended March 31, 2015. The Company’s effective tax rates were 58% and 29% for the three months ended March 31, 2016 and 2015, respectively.

The net increase in the effective tax rate for the three months ended March 31, 2016, compared to the same period in 2015 was principally due to the unfavorable impact of Chilean income tax law reform enacted this quarter and the asset impairment recorded this quarter at Buffalo Gap II. See Note 13—Asset Impairment Expense in Item 1.—Financial Statements of this Form 10-Q for further information regarding the Buffalo Gap II asset impairment.

Our effective tax rate reflects the tax effect of significant operations outside the U.S. which are generally taxed at lower rates than the U.S. statutory rate of 35%. A future proportionate change in the composition of income before income taxes from foreign and domestic tax jurisdictions could impact our periodic effective tax rate.

Net equity in earnings of affiliates

Net equity in earnings of affiliates decreased $9 million, or 60%, to $6 million for the three months ended March 31, 2016. The decrease was primarily due to lower earnings at Guacolda.

Net loss (income) attributable to noncontrolling interests

Net loss (income) attributable to NCI decreased $164 million to $52 million for the three months ended March 31, 2016 due to Buffalo Gap II impairment, lower earnings at Tietê and Eletropaulo, partially offset by an increase at Mong Duong, which was fully operational for the first quarter of 2016, whereas only one unit was operational in March 2015.

Discontinued operations

There were no discontinued operations for the three months ended March 31, 2016 or 2015.

Net income attributable to The AES Corporation

Net income attributable to The AES Corporation decreased $16 million to $126 million in the three months ended March 31, 2016 compared to $142 million in the three months ended March 31, 2015. Key drivers of the decrease are:


•	lower operating margins at Tietê, DPL and Eletropaulo;

These decreases were partially offset by:


•	unrealized foreign currency transaction gains,


•	gains on extinguishment of debt,


•	unrealized derivative gains,


•	gain on sale of our interest in DPLER,


•	and higher interest income.

SBU Performance Analysis

Non-GAAP Measures

Adjusted Operating Margin, Adjusted PTC, Adjusted EPS, and Proportional Free Cash Flow are non-GAAP supplemental measures that are used by management and external users of our consolidated financial statements such as investors, industry analysts and lenders. The Adjusted Operating Margin, Adjusted PTC, and Proportional Free Cash Flow by SBU for the three months ended March 31, 2016 are shown below. The percentages represent the contribution by each SBU to the gross metric, excluding Corporate.

Adjusted Operating Margin

Operating Margin is defined as revenue less cost of sales. Cost of sales includes costs incurred directly by the businesses in the ordinary course of business, such as electricity and fuel purchases; O&M costs; depreciation and amortization expense; bad debt expense & recoveries; general administrative & support costs at the businesses; and gains or losses on derivatives associated with the purchase and sale of electricity or fuel.

We define Adjusted Operating Margin as Operating Margin, adjusted for the impact of NCI, excluding unrealized gains or losses related to derivative transactions.

The GAAP measure most comparable to Adjusted Operating Margin is Operating Margin. We believe that Adjusted Operating Margin better reflects the underlying business performance of the Company. Factors in this determination include the impact of NCI, where AES consolidates the results of a subsidiary that is not wholly owned by the Company, as well as the variability due to unrealized derivatives gains or losses. Adjusted Operating Margin should not be construed as an alternative to Operating Margin, which is determined in accordance with GAAP.

Adjusted PTC and Adjusted EPS

We define Adjusted PTC as pretax income from continuing operations attributable to The AES Corporation excluding gains or losses of the consolidated entity due to (a) unrealized gains or losses related to derivative transactions, (b) unrealized foreign currency gains or losses, (c) gains or losses due to dispositions and acquisitions of business interests, (d) losses due to impairments, and (e) costs due to the early retirement of debt. Adjusted PTC also includes net equity in earnings of affiliates on an after-tax basis adjusted for the same gains or losses excluded from consolidated entities.

Adjusted PTC reflects the impact of NCI and excludes the items specified in the definition above. In addition to the revenue and cost of sales reflected in Operating Margin, Adjusted PTC includes the other components of our income statement, such as general and administrative expense in the corporate segment, as well as business development costs; interest expense and interest income; other expense and other income; realized foreign currency transaction gains and losses; and net equity in earnings of affiliates.

We define Adjusted EPS as diluted earnings per share from continuing operations excluding gains or losses of both consolidated entities and entities accounted for under the equity method due to (a) unrealized gains or losses related to derivative transactions, (b) unrealized foreign currency gains or losses, (c) gains or losses due to dispositions and acquisitions of business interests, (d) losses due to impairments, and (e) costs due to the early retirement of debt.

The GAAP measure most comparable to Adjusted PTC is income from continuing operations attributable to The AES Corporation. The GAAP measure most comparable to Adjusted EPS is diluted earnings per share from continuing operations. We believe that Adjusted PTC and Adjusted EPS better reflect the underlying business performance of the Company and are considered in the Company’s internal evaluation of financial performance. Factors in this determination include the variability due to unrealized gains or losses related to derivative transactions, unrealized foreign currency gains or losses, losses due to impairments and strategic decisions to dispose of or acquire business interests or retire debt, which affect results in a given period or periods. In addition, for Adjusted PTC, earnings before tax represents the business performance of the Company before the application of statutory income tax rates and tax adjustments, including the effects of tax planning, corresponding to the various jurisdictions in which the Company operates. Adjusted PTC and Adjusted EPS should not be construed as alternatives to income from continuing operations attributable to The AES Corporation and diluted earnings per share from continuing operations, which are determined in accordance with GAAP.

Proportional Free Cash Flow

Refer to Item 2.—Management’s Discussion and Analysis of Financial Condition and Results of Operations—Capital Resources and Liquidity—Proportional Free Cash Flow (a non-GAAP measure) for the discussion and reconciliation of Proportional Free Cash Flow to its nearest GAAP measure.

Reconciliations of Non-GAAP Measures



Adjusted Operating Margin (in millions)	Three Months Ended March 31,
	2016			2015
US SBU	$	104		$	175
Andes SBU	88			99
Brazil SBU	5			40
MCAC SBU	75			78
Europe SBU	76			97
Asia SBU	18			11
Corp/Other	9			12
Intersegment Eliminations	4			(2		)
Total Adjusted Operating Margin	379			510
Noncontrolling Interests Adjustment	132			215
Derivatives Adjustment	(7		)	(4		)
Operating Margin	$	504		$	721



Adjusted PTC ⁽¹⁾(in millions)	Three Months Ended March 31,
Three Months Ended March 31,	2016			2015
US SBU	$	85		$	106
Andes SBU	61			91
Brazil SBU	(9		)	21
MCAC SBU	48			50
Europe SBU	69			85
Asia SBU	22			12
Corporate and Other	(104		)	(113		)
Total Adjusted PTC	$	172		$	252
Reconciliation to Income from continuing operations, net of tax, attributable to The AES Corporation:
Non-GAAP Adjustments:
Unrealized derivative gains	34			15
Unrealized foreign currency gains (losses)	8			(47		)
Disposition/acquisition gains	19			5
Impairment losses	(50		)	(6		)
Loss on extinguishment of debt	(1		)	(27		)
Pretax contribution	182			192
Income tax expense attributable to The AES Corporation	(56		)	(50		)
Income from continuing operations, net of tax, attributable to The AES Corporation	$	126		$	142

_____________________________


⁽¹⁾	Adjusted PTC for each segment includes the effect of intercompany transactions with other segments, except for interest, charges for certain management fees, and the write-off of intercompany balances.



Adjusted EPS	Three Months Ended March 31,
	2016				2015
Diluted earnings per share from continuing operations	$	0.19			$	0.20
Unrealized derivative (gains) ⁽¹⁾	(0.03		)		(0.01		)
Unrealized foreign currency transaction (gains) losses ⁽²⁾	(0.01		)		0.03
Disposition/acquisition (gains)	(0.02		)	⁽³⁾	(0.01		)
Impairment losses	—			⁽⁴⁾	0.01
Loss on extinguishment of debt	—				0.03			⁽⁵⁾
Adjusted EPS	$	0.13			$	0.25

_____________________________


⁽¹⁾	Unrealized derivative (gains) losses were net of income tax per share of $(0.02) and $(0.01) in the three months ended March 31, 2016 and 2015, respectively.


⁽²⁾	Unrealized foreign currency transaction (gains) losses were net of income tax per share of $(0.01) and $0.03 in the three months ended March 31, 2016 and 2015, respectively.


⁽³⁾	Amount primarily relates to the gain from the sale of DPLER of $22 million ($12 million, or $0.02 per share, net of income tax expense per share of $0.01).


⁽⁴⁾	Amount primarily relates to the asset impairment at Buffalo Gap II of $159 million, of which $49 million is attributable to AES; offset by a tax benefit of $51 million (net impact of $2 million, or $0.00 per share).


⁽⁵⁾	Amount primarily relates to the loss on early retirement of debt at the Parent Company of $26 million ($18 million, or $0.03 per share, net of income tax per share of $0.01).

US SBU

The following table summarizes Operating Margin, Adjusted Operating Margin, Adjusted PTC, and Proportional Free Cash Flow ($ in millions) for our US SBU for the periods indicated:



	Three Months Ended March 31,
	2016			2015			$ Change			% Change
Operating Margin	$	114		$	173		$	(59	)	-34	%
Noncontrolling Interests Adjustment	(14		)	(2		)
Derivatives Adjustment	4			4
Adjusted Operating Margin	$	104		$	175		$	(71	)	-41	%
Adjusted PTC	$	85		$	106		$	(21	)	-20	%
Proportional Free Cash Flow	$	133		$	155		$	(22	)	-14	%

Operating Margin for the three months ended March 31, 2016 decreased by $59 million, or 34%, which was driven primarily by the following (in millions):



DPL
Impact of lower wholesale prices and completion of DP&L’s required transition to a competitive-bid market, as well as unfavorable weather and lower generation driven by plant outages in 2016	$	(65	)
Increase in RTO capacity and other margin, as these costs have decreased due to no longer serving DP&L retail load	29
Other	(6		)
Total DPL Decrease	(42		)
IPL
Lower retail margin driven by unfavorable weather	(6		)
Lower wholesale margin due to lower market prices of electricity and outages	(1		)
Total IPL Decrease	(7		)
US Generation
Impact from sale of Armenia Mountain in July 2015	(6		)
Laurel Mountain, primarily due to a decline in the PJM energy and regulation prices	(5		)
Other	1
Total US Generation Decrease	(10		)
Total US SBU Operating Margin Decrease	$	(59	)

Adjusted Operating Margin decreased by $71 million for the US SBU due to the drivers above, adjusted for NCI and excluding unrealized gains and losses on derivatives. AES owns 100% of its businesses in the U.S. with the exception of IPL, which is wholly owned by its indirect subsidiary IPALCO. As of March 31, 2016, IPALCO is owned by AES U.S. Investments (82.35%) and CDPQ (17.65%), and AES U.S. Investments is owned by AES U.S. Holdings, LLC (85%) and CDPQ (15%).

Adjusted PTC decreased by $21 million, driven by the $71 million decrease in Adjusted Operating Margin described above, partially offset by a gain on contract termination at DP&L and lower interest expense at IPL in part due to the sell-down impacts as discussed above.

Proportional Free Cash Flow decreased by $22 million driven by $71 million decrease in Adjusted Operating Margin as described above and $16 million for timing of accounts payable payments at IPL; offset favorably by $33 million in increased collections at DPL, $21 million for timing of fuel purchases at our US utilities and $13 million of lower pension contributions at IPL.

ANDES SBU

The following table summarizes Operating Margin, Adjusted Operating Margin, Adjusted Proportional Free Cash Flow ($ in millions) for our Andes SBU for the periods indicated:



	Three Months Ended March 31,
	2016			2015			$ Change			% Change
Operating Margin	$	123		$	131		$	(8	)	-6	%
Noncontrolling Interests Adjustment	(35		)	(32		)
Adjusted Operating Margin	$	88		$	99		$	(11	)	-11	%
Adjusted PTC	$	61		$	91		$	(30	)	-33	%
Proportional Free Cash Flow	$	4		$	17		$	(13	)	-76	%

Including unfavorable FX and remeasurement impacts of $16 million, operating margin for the three months ended March 31, 2016 decreased by $8 million, or 6%, which was driven primarily by the following (in millions):



Chivor
Lower contract and ancillary services sales, mainly related to lower generation as a result of lower dam level at the start of 2016	$	(11	)
Unfavorable FX impact	(7		)
Total Chivor Decrease	(18		)
Gener
Lower spot prices on energy and coal purchases	14
Lower fixed costs, mainly associated to lower maintenance expenses and lower salaries	8
Termination of Nueva Renca tolling agreement from 2015, offset by higher spot sales	(7		)
Other	(3		)
Total Gener Increase	12
Argentina
Higher fixed costs, mainly driven by higher inflation and timing of major maintenance	(20		)
Unfavorable FX impact	(9		)
Higher rates driven by annual price review and additional charges introduced by Resolution 482	28
Other	(1		)
Total Argentina Decrease	(2		)
Total Andes SBU Operating Margin Decrease	$	(8	)

Adjusted Operating Margin decreased by $11 million due to the drivers above, adjusted for the impact of NCI. AES owned 71% of Gener and Chivor as of March 31, 2015 and 67% as of December 2015, and 100% of AES Argentina.

Adjusted PTC decreased by $30 million, due to the decrease of $11 million in Adjusted Operating Margin described above, as well as lower equity earnings in Guacolda, higher realized FX losses, and higher interest expenses and lower interest income mainly associated with a one-time interest recognition on long-term financing receivables in Argentina.

Proportional Free Cash Flow decreased by $13 million, which includes the $11 million decrease in Adjusted Operating Margin as described above, as well as $25 million of higher tax payments mainly associated with withholding taxes paid on Chilean distributions. These impacts were partially offset by $23 million favorable variance at Chivor mainly related to higher collections from previous periods, and $9 million lower environmental capital expenditures at Gener associated with emissions reduction investments at the Tocopilla and Ventanas plants.

BRAZIL SBU

The following table summarizes Operating Margin, Adjusted Operating Margin, Adjusted PTC, and Proportional Free Cash Flow ($ in millions) for our Brazil SBU for the periods indicated:



	Three Months Ended March 31,
	2016			2015			$ Change			% Change
Operating Margin	$	39		$	177		$	(138	)	-78	%
Noncontrolling Interests Adjustment	(34		)	(137		)
Adjusted Operating Margin	$	5		$	40		$	(35	)	-88	%
Adjusted PTC	$	(9	)	$	21		$	(30	)	-143	%
Proportional Free Cash Flow	$	34		$	(47	)	$	81		172	%

Including unfavorable FX impacts of $10 million, operating margin for the three months ended March 31, 2016 decreased by $138 million, or 78%, which was driven primarily by the following (in millions):



Sul
Lower demand due to economic decline and higher technical and non-technical losses	$	(19	)
Higher tariffs	16
Other	(2		)
Total Sul Decrease	(5		)
Eletropaulo
Higher fixed costs driven by penalties and higher bad debt expense	(42		)
Negative impact of spot market due to over-contracted position	(15		)
Lower demand due to economic decline	(13		)
Higher tariffs	31
Other	2
Total Eletropaulo Decrease	(37		)
Tietê
Lower rates as energy sold under new contracts at lower prices	(53		)
Unfavorable FX impacts	(15		)
Lower volume of energy sold	(13		)
Lower spot prices/volume	(5		)
Other	(4		)
Total Tietê Decrease	(90		)
Other Business Drivers	(6		)
Total Brazil SBU Operating Margin Decrease	$	(138	)

Adjusted Operating Margin decreased by $35 million, primarily due to the drivers discussed above, adjusted for the impact of NCI. AES owns 16% of Eletropaulo, 46% of Uruguaiana, 100% of Sul and 24% of Tietê.

Adjusted PTC decreased by $30 million due to the decrease of $35 million in Adjusted Operating Margin as described above, as well as higher interest expense driven by higher debt and interest rates in 2016 at Eletropaulo and Sul. These results were partially offset by favorable interest income recognized on receivables at Eletropaulo and Sul.

Proportional Free Cash Flow increased by $81 million driven by favorable timing of $198 million in collections on regulatory assets at Eletropaulo and Sul, as well as the timing of $32 million in energy purchases at Tietê. These favorable impacts were offset by the $35 million decrease in Adjusted Operating Margin as described above, as well as the unfavorable timing of $93 million in payments for energy purchases and regulatory liabilities at Sul, and $43 million of higher payments on regulatory charges at Eletropaulo.

MCAC SBU

The following table summarizes Operating Margin, Adjusted Operating Margin, Adjusted PTC, and Proportional Free Cash Flow ($ in millions) for our MCAC SBU for the periods indicated:



	Three Months Ended March 31,
	2016			2015			$ Change			% Change
Operating Margin	$	96		$	103		$	(7	)	-7	%
Noncontrolling Interests Adjustment	(22		)	(23		)
Derivatives Adjustment	1			(2		)
Adjusted Operating Margin	$	75		$	78		$	(3	)	-4	%
Adjusted PTC	$	48		$	50		$	(2	)	-4	%
Proportional Free Cash Flow	$	13		$	114		$	(101	)	-89	%

Operating margin for the three months ended March 31, 2016 decreased by $7 million, or 7%, which was driven primarily by the following (in millions):



Dominican Republic
Lower fuel costs due to timing of cargoes	$	13
Higher availability and lower related fixed costs	6
Lower gas sales to third parties due to lower demand	(4		)
Other	(1		)
Total Dominican Republic Increase	14
Mexico
Lower availability and related costs	(8		)
Asset Retirement Obligation recognized in the first quarter of 2016	(4		)
Other	(3		)
Total Mexico Decrease	(15		)
Other Business Drivers	(6		)
Total MCAC SBU Operating Margin Decrease	$	(7	)

Adjusted Operating Margin decreased by $3 million due to the drivers above, adjusted for the impact of NCI and excluding unrealized gains and losses on derivatives. AES owns 90% of Changuinola and 49% of its other generation facilities in Panama, 90% of Andres and Los Mina (92% in 2015) and 45% of Itabo (46% in 2015) in the Dominican Republic, 99% of TEG/TEP and 55% of Merida in Mexico, and a weighted average of 77% of its businesses in El Salvador.

Adjusted PTC decreased by $2 million, driven by the decrease of $3 million in Adjusted Operating Margin as described above.

Proportional Free Cash Flow decreased by $101 million, primarily due to the $3 million decrease in Adjusted Operating Margin described above; $26 million from unfavorable timing of collections and $25 million of higher tax payments in the Dominican Republic; and $25 million of lower collections in Puerto Rico.

EUROPE SBU

The following table summarizes Operating Margin, Adjusted Operating Margin, Adjusted PTC, and Proportional Free Cash Flow ($ in millions) for our Europe SBU for the periods indicated:



	Three Months Ended March 31,
	2016			2015			$ Change			% Change
Operating Margin	$	83		$	103		$	(20	)	-19	%
Noncontrolling Interests Adjustment	(8		)	(8		)
Derivatives Adjustment	1			2
Adjusted Operating Margin	$	76		$	97		$	(21	)	-22	%
Adjusted PTC	$	69		$	85		$	(16	)	-19	%
Proportional Free Cash Flow	$	76		$	139		$	(63	)	-45	%

Including unfavorable FX impacts of $14 million, operating margin for the three months ended March 31, 2016 decreased by $20 million, or 19%, which was driven primarily by the following (in millions):



Kazakhstan
FX impact	$	(12	)
Other	3
Total Kazakhstan Decrease	(9		)
Kilroot
Lower coal/gas spread and lower dispatch	(7		)
Reduction in capacity income due to regulatory change and FX rates	(3		)
Lower depreciation due to impairment in prior year	5
Total Kilroot Decrease	(5		)
Other Business Drivers	(6		)
Total Europe SBU Operating Margin Decrease	$	(20	)

Adjusted Operating Margin decreased by $21 million due to the drivers above, adjusted for NCI and excluding unrealized gains and losses on derivatives. AES owns 89% of Kavarna in Bulgaria, and 37% and 36% respectively, of the Amman East and IPP4 projects in Jordan.

Adjusted PTC decreased by $16 million as a result of the decrease of $21 million in Adjusted Operating Margin described above, partially offset by lower interest expense in Bulgaria due to less debt.

Proportional Free Cash Flow decreased by $63 million, driven by the $21 million decrease in Adjusted Operating Margin as described above, $21 million for higher payments to fuel suppliers at Maritza, $16 million from the timing of collections received at Ballylumford in the prior year, and $7 million of non-recurring cash taxes paid at Kilroot; partially offset by $15 million of higher collections in Bulgaria.

ASIA SBU

The following table summarizes Operating Margin, Adjusted Operating Margin, Adjusted PTC, and Proportional Free Cash Flow ($ in millions) for our Asia SBU for the periods indicated:



	Three Months Ended March 31,
	2016			2015			$ Change		% Change
Operating Margin	$	37		$	24		$	13	54	%
Noncontrolling Interests Adjustment	(19		)	(13		)
Adjusted Operating Margin	$	18		$	11		$	7	64	%
Adjusted PTC	$	22		$	12		$	10	83	%
Proportional Free Cash Flow	$	43		$	4		$	39	975	%

Operating margin for the three months ended March 31, 2016 increased by $13 million, or 54%, which was driven primarily by the following (in millions):



Mong Duong
Impact of full operations being online throughout the first quarter of 2016, compared to only Unit 1 coming online March 4, 2015	$	11
Total Mong Duong Increase	11
Other business drivers	2
Total Asia SBU Operating Margin Increase	$	13

Adjusted Operating Margin increased by $7 million due to the drivers above adjusted for the impact of NCI. AES owns 51% of Masinloc, 90% of Kelanitissa (prior to sale in January 2016) and 51% of Mong Duong.

Adjusted PTC increased by $10 million, primarily due to the increase of $7 million in Adjusted Operating Margin described above, and a net impact of $4 million at Mong Duong due to a component of service concession revenue recognized as interest income, net of higher interest expense as interest is no longer capitalized.

Proportional Free Cash Flow increased by $39 million, which was primarily driven by the increase of $7 million in Adjusted Operating Margin and $18 million from the prior year buildup of working capital requirements in preparation for commencement of plant operations.

Key Trends and Uncertainties

During the remainder of 2016 and beyond, we expect to face the following challenges at certain of our businesses. Management expects that improved operating performance at certain businesses, growth from new businesses and global cost reduction initiatives may lessen or offset their impact. If these favorable effects do not occur, or if the challenges described below and elsewhere in this section impact us more significantly than we currently anticipate, or if volatile foreign currencies and commodities move more unfavorably, then these adverse factors, a combination of factors, (or other adverse factors unknown to us) may have a material impact on our operating margin, net income attributable to The AES Corporation and cash flows. We continue to monitor our operations and address challenges as they arise.

Operational

Sensitivity to Hydrological Conditions — Our hydroelectric generation facilities are sensitive to changes in the weather, particularly the level of water inflows into generation facilities. Since 2013, dry hydrological conditions in Panama, Brazil, Colombia and Chile have presented challenges for our businesses in these markets. While these dry conditions are expected to continue to abate over the course of 2016, there still remains a risk that low rainfall and water inflows could reduce reservoir levels, generation output, and increase prices for electricity. Alternatively, wet conditions could also have an adverse impact by depressing spot prices for excess energy sales for generation businesses. For distribution businesses, wet conditions could result in lowered demand as well as floods and other damage which could disrupt service and require emergency repairs. Future hydrology conditions are always uncertain, but currently the Company does not expect a material impact due to hydrology in 2016.

Macroeconomic and Political

During the past few years, economic conditions in some countries where our subsidiaries conduct business have deteriorated. Global economic conditions remain volatile and could have an adverse impact on our businesses in the event these recent trends continue.

Brazil — In Brazil, economic conditions remain unfavorable, as indicated by such factors as higher interest rates and inflation, increasing unemployment, and a negative GDP growth rate for 2015, which is expected to continue for the remainder of 2016 and recover only to a flat growth rate in 2017. As a consequence, our distribution businesses have experienced a decline in demand. If these economic conditions persist or worsen, there could be a material impact on our businesses and AES’ results of operations, particularly in our distribution businesses in Brazil, AES Sul and AES Eletropaulo. In addition, the political landscape in Brazil remains uncertain. In April 2016, impeachment proceedings were initiated against Brazilian president Dilma Rousseff. It is too early to determine the impact that any resulting changes to the government will have on our businesses.

In March 2016, AES Sul completed a restructuring of its debt, which involved extending the debt maturities and obtaining additional equity contributions of approximately $73 million. As a result, AES Sul reclassified $327 million of debt that was previously in default to long-term, according to the new terms.

In addition, AES Sul has deferred tax assets (“DTA”) of $151 million as of March 31, 2016, relating primarily to net operating loss carryforwards, which are not subject to expiration. Realization is dependent on generating sufficient taxable income. Although realization is not assured, management believes it is more likely than not that all

of the DTA will be realized. The amount of DTA that is considered realizable, however, could be reduced in the near term if estimates of future taxable income are reduced.

Bulgaria — As of March 31, 2016, Maritza’s total outstanding receivables were $368 million, of which $26 million were current and $342 million were overdue. On April 26, 2016, Maritza received payments from NEK totaling $291 million pursuant to the previously disclosed PPA amendment executed in August 2015. In addition to this payment, NEK directly paid $57 million to MMI, a Maritza fuel supplier, for invoices due to MMI from Maritza. See additional background within our 2015 Form 10-K—Part I.—Item 1—Business—Our Organization and Segments—Europe—Bulgaria—Regulatory Framework.

Puerto Rico — Our subsidiaries in Puerto Rico have long term PPAs with state-owned PREPA. Due to the ongoing economic situation in the territory, PREPA faces significant financial challenges.

On June 28, 2014, the Puerto Rico Public Corporation Debt Enforcement and Recovery Act (the “Recovery Act”) was signed into law, which allows public corporations, including PREPA, to adjust their debts. As a result of this event, on July 6, 2014, PREPA entered into a Forbearance Agreement with its lenders in order to permit an opportunity for negotiation of a possible financial restructuring of PREPA. In February 2015, the negotiating position of PREPA was weakened when the federal court deemed the Recovery Act unconstitutional. Despite this setback, PREPA managed to extend the expiration of the Forbearance Agreement several times, achieving in December 2015 certain preliminary restructuring agreements, called Restructuring Support Agreements (“RSAs”). Under these agreements, bondholders would take a reduction in principal after exchanging their bonds for new securities that would be backed by a special charge on clients’ bills. For its part, the utility would receive five-year debt-service relief, while freeing up cash to modernize its power plants. The RSAs are conditional to a series of future related milestones, the more important of which being (i) the passing of a bill that would allow an increase in tariffs and the implementation of the above mentioned special charge in the tariff, and (ii) the filing of a petition to the Puerto Rico Energy Commission (“PREC”) seeking approval of a proposal for the special charge and its adjustment mechanism.

The next step in accordance with the RSA is to sign a Bond Purchase Agreement between PREPA and the lenders for the new securities to be issued.

There has been no adverse impacts to AES Puerto Rico due to PREPA’s financial challenges. AES Puerto Rico’s receivables balance as of March 31, 2016, is $79 million, of which $25 million was overdue. Subsequent to March 31, 2016, the full overdue amount has been collected. If the situation declines, there could be a material impact on the Company.

Macroeconomic and Political — Summary

If global economic conditions deteriorate further, it could also affect the prices we receive for the electricity we generate or transmit. Utility regulators or parties to our generation contracts may seek to lower our prices based on prevailing market conditions pursuant to PPAs, concession agreements or other contracts as they come up for renewal or reset. In addition, rising fuel and other costs coupled with contractual price or tariff decreases could restrict our ability to operate profitably in a given market. Additionally, we operate in multiple countries and as such are subject to volatility in exchange rates at the subsidiary level and between our functional currency, the U.S. Dollar, and currencies of the countries in which we operate. The above mentioned market drivers have already impacted us significantly in 2016 and we expect them to continue to do so during the remainder of the year. See Item 3.—Quantitative and Qualitative Disclosures About Market Risk for further information. Each of these factors, as well as those discussed above, could result in a decline in the value of our assets including those at the businesses we operate, our equity investments and projects under development could result in asset impairments that could be material to our operations. We continue to monitor our projects and businesses.

Regulatory

In March 2016, the IURC issued an order authorizing IPL to increase its basic rates and charges by approximately $31 million annually. The order also authorized IPL to collect over a ten-year period, approximately $118 million of previously deferred regulatory assets related to IPL’s participation in the regional transmission organization known as MISO. Such deferred costs will be amortized to expense over ten years. Accordingly, $12 million of IPL's long-term MISO regulatory asset as of December 31, 2015, has been reclassified to current regulatory assets as of March 31, 2016, on the Company’s Condensed Consolidated Balance Sheets. The rate order also authorized an increase in IPL’s depreciation rates of $24 million annually compared to the twelve months ended June 30, 2014, which is the period upon which the rate increase was calculated. IPL also received approval to implement three new rate riders for current recovery of ongoing MISO costs, capacity costs and sharing of wholesale sales margins with customers at 50%. The order approved recovery of IPL’s pension expenses and return on IPL’s discretionary pension fundings. As part of the order, the IURC also noted that they found IPL’s

service company cost allocations to be reasonable and directed IPL to request FERC to review its Service Company allocations. The IURC also closed their investigation into IPL’s underground network. Some of the intervening parties in the IURC rate case have filed petitions for reconsideration of the IURC's March 2016 order with respect to certain issues. The IURC has not yet acted on those petitions. In addition, the Indiana Office of Utility Consumer Counselor and some other intervening parties have filed notices of appeal of the order.

Foreign Exchange and Commodities

Our businesses are exposed to and proactively manage market risk. Our primary market risk exposure is to the price of commodities, particularly electricity, oil, natural gas, coal, and environmental credits. In 2015, large declines in commodities and appreciation in the USD had a significant impact on our results. During the first quarter of 2016, commodities and FX have remained volatile; continued volatility in these markets could have a material impact on our full year 2016 results. For additional information, refer to Item 3.—Quantitative and Qualitative Disclosures About Market Risk.

Impairments

Long-lived Assets — During the three months ended March 31, 2016, the Company recognized an asset impairment expense of $159 million ($49 million attributable to AES) at Buffalo Gap II. See Note 13—Asset Impairment Expense in Item 1.—Financial Statements in this Form 10-Q for further information. After recognizing this asset impairment expense at Buffalo Gap II, the carrying value of the long-lived asset groups at Buffalo Gap I, II, and III totaled $325 million at March 31, 2016.

Events or changes in circumstances that may necessitate further recoverability tests and potential impairments of long-lived assets may include, but are not limited to, adverse changes in the regulatory environment, unfavorable changes in power prices or fuel costs, increased competition due to additional capacity in the grid, technological advancements, declining trends in demand, or an expectation that it is more likely than not that the asset will be disposed of before the end of its previously estimated useful life.

Environmental

The Company is subject to numerous environmental laws and regulations in the jurisdictions in which it operates. The Company expenses environmental regulation compliance costs as incurred unless the underlying expenditure qualifies for capitalization under its property, plant and equipment policies. The Company faces certain risks and uncertainties related to these environmental laws and regulations, including existing and potential GHG legislation or regulations, and actual or potential laws and regulations pertaining to water discharges, waste management (including disposal of coal combustion byproducts) and certain air emissions, such as SO₂, NO_x, particulate matter and mercury. Such risks and uncertainties could result in increased capital expenditures or other compliance costs which could have a material adverse effect on certain of our U.S. or international subsidiaries and our consolidated results of operations. For further information about these risks, see Item 1A.—Risk Factors—Our businesses are subject to stringent environmental laws and regulations; Our businesses are subject to enforcement initiatives from environmental regulatory agencies; and Regulators, politicians, non-governmental organizations and other private parties have expressed concern about greenhouse gas, or GHG, emissions and the potential risks associated with climate change and are taking actions which could have a material adverse impact on our consolidated results of operations, financial condition and cash flows in the 2015 Form 10-K. The following discussion of the impact of environmental laws and regulations on the Company updates the discussion provided in Item 1.—Business—Environmental and Land Use Regulations of the 2015 Form 10-K.

Update on Greenhouse Gas Emissions Regulation — As discussed in Item 1.—Business—United States Environmental and Land Use Regulations—Greenhouse Gas Emissions in the Company's 2015 Form 10-K, several states and industry groups filed petitions in the United States Court of Appeals for the District of Columbia Circuit (the “D.C. Circuit”) challenging the United States Environmental Protection Agency’s final CO₂ emissions rules for existing power plants under Clean Air Act Section 111(d) (called the Clean Power Plan (the “CPP”)). On February 9, 2016, the U.S. Supreme Court issued orders staying implementation of the CPP pending resolutions of challenges to the rule.

Update on Waste Management — As discussed in Item 1.—Business—United States Environmental and Land Use Regulations—Waste Management Regulation in the Company's 2015 Form 10-K, the EPA’s rule regulating coal combustion residue (“CCR”) under the Resource Conservation and Recovery Act became effective in October 2015. The rule established nationally applicable minimum criteria for the disposal of CCR in new and currently operating landfills and surface impoundments, and may impose closure and/or corrective action requirements for existing CCR landfills and impoundments under certain specified conditions. We expect that this rule will require IPL to cease use of ash ponds at its Petersburg plant, which will necessitate construction of a

bottom ash de-watering system. IPL has engaged an engineering firm to further assess associated costs. While costs cannot be accurately predicted at this time, they may be material.

Capital Resources and Liquidity

Overview — As of March 31, 2016, the Company had unrestricted cash and cash equivalents of $1.2 billion, of which $17 million was held at the Parent Company and qualified holding companies. The Company had $628 million in short-term investments, held primarily at subsidiaries. In addition, we had restricted cash and debt service reserves of $709 million. The Company also had non-recourse and recourse aggregate principal amounts of debt outstanding of $15.6 billion and $4.9 billion, respectively. Of the approximately $2.2 billion of our current non-recourse debt, $1.5 billion was presented as such because it is due in the next 12 months and $695 million relates to debt considered in default due to covenant violations. The defaults are not payment defaults, but are instead technical defaults triggered by failure to comply with other covenants and/or conditions such as (but not limited to) failure to meet information covenants, complete construction or milestones in an allocated time, and meet minimum or maximum financial ratios, or other requirements contained in the non-recourse debt documents of the Company.

We expect such current maturities will be repaid from net cash provided by operating activities of the subsidiary to which the debt relates, through opportunistic refinancing activity, or some combination thereof. None of our recourse debt matures within the next twelve months. From time to time, we may elect to repurchase our outstanding debt through cash purchases, privately negotiated transactions or otherwise when management believes that such securities are attractively priced. Such repurchases, if any, will depend on prevailing market conditions, our liquidity requirements and other factors. The amounts involved in any such repurchases may be material.

We rely mainly on long-term debt obligations to fund our construction activities. We have, to the extent available at acceptable terms, utilized non-recourse debt to fund a significant portion of the capital expenditures and investments required to construct and acquire our electric power plants, distribution companies and related assets. Our non-recourse financing is designed to limit cross-default risk to the Parent Company or other subsidiaries and affiliates. Our non-recourse long-term debt is a combination of fixed and variable interest rate instruments. Generally, a portion or all of the variable rate debt is fixed through the use of interest rate swaps. In addition, the debt is typically denominated in the currency that matches the currency of the revenue expected to be generated from the benefiting project, thereby reducing currency risk. In certain cases, the currency is matched through the use of derivative instruments. The majority of our non-recourse debt is funded by international commercial banks, with debt capacity supplemented by multilaterals and local regional banks.

Given our long-term debt obligations, the Company is subject to interest rate risk on debt balances that accrue interest at variable rates. When possible, the Company will borrow funds at fixed interest rates or hedge its variable rate debt to fix its interest costs on such obligations. In addition, the Company has historically tried to maintain at least 70% of its consolidated long-term obligations at fixed interest rates, including fixing the interest rate through the use of interest rate swaps. These efforts apply to the notional amount of the swaps compared to the amount of related underlying debt. Presently, the Parent Company’s only material unhedged exposure to variable interest rate debt relates to indebtedness under its floating rate senior unsecured notes due 2019. On a consolidated basis, of the Company’s $15.6 billion of total non-recourse debt outstanding as of March 31, 2016, approximately $3.7 billion bore interest at variable rates that were not subject to a derivative instrument which fixed the interest rate.

In addition to utilizing non-recourse debt at a subsidiary level when available, the Parent Company provides a portion, or in certain instances all, of the remaining long-term financing or credit required to fund development, construction or acquisition of a particular project. These investments have generally taken the form of equity investments or intercompany loans, which are subordinated to the project’s non-recourse loans. We generally obtain the funds for these investments from our cash flows from operations, proceeds from the sales of assets and/or the proceeds from our issuances of debt, common stock and other securities. Similarly, in certain of our businesses, the Parent Company may provide financial guarantees or other credit support for the benefit of counterparties who have entered into contracts for the purchase or sale of electricity, equipment or other services with our subsidiaries or lenders. In such circumstances, if a business defaults on its payment or supply obligation, the Parent Company will be responsible for the business’ obligations up to the amount provided for in the relevant guarantee or other credit support. At March 31, 2016, the Parent Company had provided outstanding financial and performance-related guarantees, indemnities or other credit support commitments to or for the benefit of our businesses, which were limited by the terms of the agreements, of approximately $382 million in aggregate (excluding those collateralized by letters of credit and other obligations discussed below). These amounts exclude normal and customary representations and warranties in agreements for the sale of assets (including ownership in associated legal entities) where the associated risk is considered to be nominal.

As a result of the Parent Company’s below-investment-grade rating, counterparties may be unwilling to accept our general unsecured commitments to provide credit support. Accordingly, with respect to both new and existing commitments, the Parent Company may be required to provide some other form of assurance, such as a letter of credit, to backstop or replace our credit support. The Parent Company may not be able to provide adequate assurances to such counterparties. To the extent we are required and able to provide letters of credit or other collateral to such counterparties, this will reduce the amount of credit available to us to meet our other liquidity needs. At March 31, 2016, we had $62 million in letters of credit outstanding, provided under our senior secured credit facility and $31 million in cash collateralized letters of credit outstanding outside of our senior secured credit facility. These letters of credit operate to guarantee performance relating to certain project development activities, construction activities and subsidiary operations. During the quarter ended March 31, 2016, the Company paid letter of credit fees ranging from 0.2% to 2.5% per annum on the outstanding amounts.

We expect to continue to seek, where possible, non-recourse debt financing in connection with the assets or businesses that we or our affiliates may develop, construct or acquire. However, depending on local and global market conditions and the unique characteristics of individual businesses, non-recourse debt may not be available on economically attractive terms or at all. If we decide not to provide any additional funding or credit support to a subsidiary project that is under construction or has near-term debt payment obligations and that subsidiary is unable to obtain additional non-recourse debt, such subsidiary may become insolvent, and we may lose our investment in that subsidiary. Additionally, if any of our subsidiaries lose a significant customer, the subsidiary may need to withdraw from a project or restructure the non-recourse debt financing. If we or the subsidiary choose not to proceed with a project or are unable to successfully complete a restructuring of the non-recourse debt, we may lose our investment in that subsidiary.

Many of our subsidiaries depend on timely and continued access to capital markets to manage their liquidity needs. The inability to raise capital on favorable terms, to refinance existing indebtedness or to fund operations and other commitments during times of political or economic uncertainty may have material adverse effects on the financial condition and results of operations of those subsidiaries. In addition, changes in the timing of tariff increases or delays in the regulatory determinations under the relevant concessions could affect the cash flows and results of operations of our businesses.

Long-Term Receivables — As of March 31, 2016, the Company had approximately $282 million and $69 million of accounts receivable classified as Noncurrent assets—other and Current assets—Accounts receivable, respectively, related to certain of its generation businesses in Argentina and the United States, and its utility business in Brazil. The noncurrent portion primarily consists of accounts receivable in Argentina that, pursuant to amended agreements or government resolutions, have collection periods that extend beyond March 31, 2017, or one year from the latest balance sheet date. The majority of Argentinian receivables have been converted into long-term financing for the construction of power plants. See Note 5—Financing Receivables included in Part I—Item 1.—Financial Statements of this Form 10-Q and Item 1.—Business—Regulatory Matters—Argentina included in the 2015 Form 10-K for further information.

Consolidated Cash Flows

During the three months ended March 31, 2016, cash and cash equivalents decreased $77 million to $1.2 billion. The table below reflects the changes in cash flows for the comparative periods ($ in millions):



	Three Months Ended March 31,
Cash flows provided by (used in):	2016			2015			$ Change			% Change
Operating activities	$	640		$	437		$	203		46	%
Investing activities	(548		)	(720		)	172			-24	%
Financing activities	(180		)	113			(293		)	-259	%
Effect of exchange rate changes on cash	7			(27		)	34			126	%
Increase (decrease) in cash of held-for-sale businesses	4			(5		)	9			-180	%
Total decrease in cash and cash equivalents	(77		)	(202		)	125			62	%
Cash and cash equivalents, beginning	1,262			1,539			(277		)	-18	%
Cash and cash equivalents, ending	$	1,185		$	1,337		$	(152	)	-11	%

Operating Activities

Net cash provided by operating activities increased $203 million for the three months ended March 31, 2016 compared to the three months ended March 31, 2015 driven by ($ in millions):



	Three Months Ended March 31,
	2016			2015			$ Change			% Change
Net Income	$	74		$	254		$	(180	)	-71	%
Depreciation and amortization	290			298			(8		)	-3	%
Impairment expenses	161			8			153			NM
Loss on the extinguishment of debt	(4		)	23			(27		)	-117	%
Other adjustments to net income	(20		)	66			(86		)	130	%
Adjusted net income	$	501		$	649		$	(148	)	-23	%
Net change in operating assets and liabilities ⁽¹⁾	$	139		$	(212	)	$	351		166	%
Net cash provided by operating activities⁽²⁾	$	640		$	437		$	203		46	%

NM - Not Meaningful

⁽¹⁾ Refer to the table below for explanations of the variance in operating assets and liabilities.

⁽²⁾Refer to the operating cash flow discussion by SBU for further information about the key drivers.

Net change in operating assets and liabilities increased $351 million for the three months ended March 31, 2016 compared to the three months ended March 31, 2015 driven by (in millions):



	$ Change
Decrease in accounts receivable primarily at Uruguaiana ($123), Eletropaulo ($120) and Gener ($46)	$	374
Decrease in prepaid expenses and other current assets primarily regulatory assets at Sul ($106) and Eletropaulo ($88)	206
Decrease in other assets primarily long-term regulatory assets at Eletropaulo ($251)	269
Decrease in accounts payable and other current liabilities primarily at Eletropaulo ($213), Sul ($110) and Uruguaiana ($105), partially offset by an increase at Tietê ($127)	(345		)
Decrease in income tax payables, net and other tax payables primarily at Tietê ($52), Gener ($31) and Andres ($26)	(133		)
Other operating assets and liabilities	(20		)
Total increase in operating assets and liabilities	$	351

Investing Activities

Net cash used in investing activities decreased $172 million for the three months ended March 31, 2016, compared to the three months ended March 31, 2015, driven by (in millions):



	$ Change
Increase in capital expenditures primarily due to US, MCAC and Asia SBU generation growth projects, partially offset by a decrease in growth projects at Andes SBU ⁽¹⁾	$	(21	)
Increase in proceeds from sale of business, net of cash sold primarily related to sales of DPLER for $76, Kelanitissa for $18 and Jordan for $21 at US, Asia and Europe SBUs, respectively.	115
Increase in net purchase of short-term investments	(127		)
Decrease in restricted cash, debt service and other assets	171
Other investing activity drivers	34
Total decrease in net cash used in investing activities	$	172


⁽¹⁾	Refer to table below for capital expenditures types and drivers by business.

The following table summarizes the Company's capital expenditures for growth investments, maintenance and environmental reported in investing cash activities for the periods indicated ($ in millions):



	Three Months Ended March 31,
	2016			2015			$ Change			% Change
Growth Investments	$	(392	)	$	(426	)	$	34		-8	%
Maintenance	(161		)	(147		)	(14		)	10	%
Environmental ⁽¹⁾	(87		)	(46		)	(41		)	89	%
Total capital expenditures	$	(640	)	$	(619	)	$	(21	)	3	%


⁽¹⁾	Includes both recoverable and non-recoverable environmental capital expenditures. See Non-GAAP Proportional Free Cash Flow for more information.

Cash used for capital expenditures for growth investments, maintenance, and environmental decreased $21 million for the three months ended March 31, 2016, compared to the three months ended March 31, 2015, driven by (in millions):



	$ Change
Decrease in growth expenditures primarily at Gener in Andes SBU, partially offset by an increase in growth expenditures at IPALCO, Atlantico and Los Mina in US, MCAC and Andes SBUs, respectively.	$	30
Increase in maintenance and environmental expenditures at IPALCO business in US SBU	(38		)
Other business capital expenditures	(13		)
Total decrease in net cash used for capital expenditures	$	(21	)

Financing Activities

Net cash (used in) provided by financing activities decreased $293 million for the three months ended March 31, 2016, compared to the three months ended March 31, 2015, driven by (in millions):



	$ Change
Decrease in recourse debt repayment at the Parent Company	$	220
Decrease in net non-recourse debt issuance primarily at Gener and Sul of $249 and $72, respectively, as well as increase in repayments at DPL of $75.	(392		)
Decrease in proceeds from the sale of redeemable stock of subsidiaries at IPALCO	(113		)
Increase in purchase of treasury stock at the Parent Company	(44		)
Decrease in payments for financed capital expenditures primarily at Gener of $30	32
Other financing activity drivers	4
Total decrease in net cash (used in) provided by financing activities	$	(293	)

Proportional Free Cash Flow (a non-GAAP measure)

We define Proportional Free Cash Flow as cash flows from operating activities (adjusted for service concession asset capital expenditures), less maintenance capital expenditures (including non-recoverable environmental capital expenditures and net of reinsurance proceeds), adjusted for the estimated impact of NCI. The proportionate share of cash flows and related adjustments attributable to NCI in our subsidiaries comprise the proportional adjustment factor presented in the reconciliation below. Upon the Company’s adoption of the accounting guidance for service concession arrangements effective January 1, 2015, capital expenditures related to service concession assets that would have been classified as investing activities on the Condensed Consolidated Statement of Cash Flows are now classified as operating activities. See Note 1—Financial Statement Presentation of this Form 10-Q for further information on the adoption of this guidance.

Beginning in the quarter ended March 31, 2015, the Company changed the definition of Proportional Free Cash Flow to exclude the cash flows for capital expenditures related to service concession assets that are now classified within net cash provided by operating activities on the Condensed Consolidated Statement of Cash Flows. The proportional adjustment factor for these capital expenditures is presented in the reconciliation below.

We exclude environmental capital expenditures that are expected to be recovered through regulatory, contractual or other mechanisms. An example of recoverable environmental capital expenditures is IPL’s investment in MATS-related environmental upgrades that are recovered through a tracker. See Item 1.—Business—US SBU—IPALCO—Environmental Matters in our 2015 Form 10-K for details of these investments.

The GAAP measure most comparable to proportional free cash flow is cash flows from operating activities. We believe that proportional free cash flow better reflects the underlying business performance of the Company, as it measures the cash generated by the business, after the funding of maintenance capital expenditures, that may be available for investing or repaying debt or other purposes. Factors in this determination include the impact of NCI, where AES consolidates the results of a subsidiary that is not wholly owned by the Company.

The presentation of free cash flow has material limitations. Proportional free cash flow should not be construed as an alternative to cash from operating activities, which is determined in accordance with GAAP. Proportional free cash flow does not represent our cash flow available for discretionary payments because it excludes certain payments that are required or to which we have committed, such as debt service requirements and dividend payments. Our definition of proportional free cash flow may not be comparable to similarly titled measures presented by other companies.



	Three Months Ended March 31,
Calculation of Proportional Free Cash Flow ($ in millions)	2016			2015			$ Change			% Change
Net Cash provided by operating activities	$	640		$	437		$	203		46	%
Add: capital expenditures related to service concession assets ⁽¹⁾	24			20			4			20	%
Adjusted Operating Cash Flow	$	664		$	457		$	207		45	%
Less: proportional adjustment factor on operating cash activities ^{(2) (3)}	(289		)	(72		)	(217		)	-301	%
Proportional Adjusted Operating Cash Flow	$	375		$	385		$	(10	)	-3	%
Less: proportional maintenance capital expenditures, net of reinsurance proceeds ⁽²⁾	(112		)	(113		)	1			1	%
Less: proportional non-recoverable environmental capital expenditures ^{(2) (4)}	(10		)	(7		)	(3		)	-43	%
Proportional Free Cash Flow	$	253		$	265		$	(12	)	-5	%

____________________________


⁽¹⁾	Service concession asset expenditures excluded from proportional free cash flow non-GAAP metric.

⁽²⁾

The proportional adjustment factor, proportional maintenance capital expenditures (net of reinsurance proceeds) and proportional non-recoverable environmental capital expenditures are calculated by multiplying the percentage owned by noncontrolling interests for each entity by its corresponding consolidated cash flow metric and are totaled to the resulting figures. For example, Parent Company A owns 80% of Subsidiary Company B, a consolidated subsidiary. Thus, Subsidiary Company B has a 20% noncontrolling interest. Assuming a consolidated net cash flow from operating activities of $100 from Subsidiary B, the proportional adjustment factor for Subsidiary B would equal ($20), or $100 x (20%). The Company calculates the proportional adjustment factor for each consolidated business in this manner and then sums these amounts to determine the total proportional adjustment factor used in the reconciliation. The proportional adjustment factor may differ from the proportion of income attributable to noncontrolling interests as a result of (a) non-cash items which impact income but not cash and (b) AES'

ownership interest in the subsidiary where such items occur.


⁽³⁾	Includes proportional adjustment amount for service concession asset expenditures of $12 million and $10 million for the three months ended March 31, 2016 and 2015, respectively.


⁽⁴⁾	Excludes IPALCO’s proportional recoverable environmental capital expenditures of $56 million and $37 million for the three months ended March 31, 2016 and 2015, respectively.

Operating Cash Flow and Proportional Free Cash Flow Analysis ⁽¹⁾



	Operating Cash Flow by Segment											Proportional Free Cash Flow by Segment
($ in millions)	2016			2015			$ Change			% Change		2016			2015			$ Change			% Change
US	$	207		$	212		$	(5	)	-2	%	$	133		$	155		$	(22	)	-14	%
Andes	38			60			(22		)	-37	%	4			17			(13		)	-76	%
Brazil	241			(31		)	272			877	%	34			(47		)	81			172	%
MCAC	39			162			(123		)	-76	%	13			114			(101		)	-89	%
Europe	92			153			(61		)	-40	%	76			139			(63		)	-45	%
Asia	72			(2		)	74			NM		43			4			39			975	%
Corporate	(49		)	(117		)	68			58	%	(50		)	(117		)	67			57	%
Total	$	640		$	437		$	203		46	%	$	253		$	265		$	(12	)	-5	%

NM - Not Meaningful


⁽¹⁾	Operating cash flow and proportional free cash flow as presented above include the effect of intercompany transactions with other segments except for interest, tax sharing, charges for management fees and transfer pricing.

US SBU

The following table summarizes Operating Cash Flow and Proportional Free Cash Flow (in millions) for our US SBU for the periods indicated:



	Three Months Ended March 31,
Calculation of Proportional Free Cash Flow	2016			2015			$ Change
Net Cash Provided by Operating Activities	$	207		$	212		$	(5	)
Less: proportional adjustment factor on operating cash activities	(19		)	(3		)	(16		)
Proportional Adjusted Operating Cash Flow	188			209			(21		)
Less: proportional maintenance capital expenditures, net of reinsurance proceeds	(54		)	(53		)	(1		)
Less: proportional non-recoverable environmental capital expenditures ⁽¹⁾	(1		)	(1		)	—
Proportional Free Cash Flow	$	133		$	155		$	(22	)


⁽¹⁾	Excludes IPL's proportional recoverable environmental capital expenditures of $56 million and $37 million for the three months ended March 31, 2016 and 2015, respectively.

Operating Cash Flow for the three months ended March 31, 2016, compared to the three months ended March 31, 2015, decreased $5 million, driven primarily by the following businesses (in millions):



US SBU	Amount
DPL
Lower operating margin resulting from lower wholesale prices, unfavorable weather and lower generation due to plant outages	$	(42	)
Increased collections	33
Timing of coal inventory purchases and accounts payable payments in the prior year	24
Other	2
Total DPL Increase	17
IPL
Timing of accounts payable payments primarily related to maintenance expenses in the prior year	(17		)
Increased interest payments due to refinancing of new debt instruments in 2016	(8		)
Decreased contributions to defined benefit plans	9
Lower coal inventory purchases due to ongoing plant conversion to natural gas	8
Other	1
Total IPL Decrease	(7		)
US Generation
Timing of annual property insurance premium payments to Corporate due to start of policy moving to calendar year	(10		)
Other	(5		)
Total US Generation Decrease	(15		)
Total US SBU Operating Cash Decrease	$	(5	)

Proportional Free Cash Flow for the three months ended March 31, 2016, compared to the three months ended March 31, 2015, decreased $22 million, due to the drivers above, as well as a $1 million net increase in maintenance and non-recoverable capital expenditures and adjusted for the impact of noncontrolling interest as a result of the sell-down of IPL in 2016.

ANDES SBU

The following table summarizes Operating Cash Flow and Proportional Free Cash Flow (in millions) for our Andes SBU for the periods indicated:



	Three Months Ended March 31,
Calculation of Proportional Free Cash Flow	2016			2015			$ Change
Net Cash Provided by Operating Activities	$	38		$	60		$	(22	)
Less: proportional adjustment factor on operating cash activities	(20		)	(17		)	(3		)
Proportional Adjusted Operating Cash Flow	18			43			(25		)
Less: proportional maintenance capital expenditures, net of reinsurance proceeds	(11		)	(20		)	9
Less: proportional non-recoverable environmental capital expenditures	(3		)	(6		)	3
Proportional Free Cash Flow	$	4		$	17		$	(13	)

Operating Cash Flow for the three months ended March 31, 2016, compared to the three months ended March 31, 2015, decreased $22 million, driven primarily by the following businesses (in millions):



Andes SBU	Amount
Chivor
Lower operating margin due to lower contract and ancillary sales resulting from lower generations	$	(18	)
Higher collections	35
Other	(12		)
Total Chivor Increase	5
Gener
Higher operating margin primarily due to lower spot prices on energy and coal purchases	12
Timing of collections in the prior year	46
Higher withholding taxes paid on Chilean distributions	(33		)
Timing of annual property insurance premium payments to Corporate due to start of policy moving to calendar year	(23		)
Timing of coal inventory purchases in the current year	(13		)
Other	(3		)
Total Gener Decrease	(14		)
Argentina
Timing of annual property insurance premium payments payments to Corporate due to start of policy moving to calendar year	(7		)
Higher taxes paid on prior year taxable income	(5		)
Other	(1		)
Total Argentina Increase	(13		)
Total	$	(22	)

Proportional Free Cash Flow for the three months ended March 31, 2016, compared to the three months ended March 31, 2015, decreased $13 million, due to the drivers above, partially offset by a $12 million net decrease in maintenance and non-recoverable environmental capital expenditures and adjusted for the impact of noncontrolling interest.

BRAZIL SBU

The following table summarizes Operating Cash Flow and Proportional Free Cash Flow (in millions) for our Brazil SBU for the periods indicated:



	Three Months Ended March 31,
Calculation of Proportional Free Cash Flow	2016			2015			$ Change
Net Cash Provided by Operating Activities	$	241		$	(31	)	$	272
Less: proportional adjustment factor on operating cash activities	(190		)	—			(190		)
Proportional Adjusted Operating Cash Flow	51			(31		)	82
Less: proportional maintenance capital expenditures, net of reinsurance proceeds	(17		)	(16		)	(1		)
Proportional Free Cash Flow	$	34		$	(47	)	$	81

Operating Cash Flow for the three months ended March 31, 2016, compared to the three months ended March 31, 2015, increased $272 million, driven primarily by the following businesses (in millions):



Brazil SBU	Amount
Sul
Timing of collections of regulatory assets in the current year	$	142
Timing of payments of energy purchases and regulatory liabilities in the current year	(93		)
Other	(9		)
Total Sul Increase	40
Eletropaulo
Lower margin due to higher fixed costs, lower spot prices, lower demands offset by higher tariffs	(37		)
Net impact of timing on collections of regulatory assets and lower payments of regulatory liabilities in the current year	353
Timing on collections of higher tariffs in the current year	120
Higher payments on regulatory charges in the current year	(269		)
Other	13
Total Eletropaulo Increase	180
Tietê
Lower margin due lower price contracted energy sales and lower spot sales	(90		)
Lower energy purchases in spot market in the current year as result of favorable hydrology	132
Other	10
Total Tietê Increase	52
Total Brazil SBU Operating Cash Increase	$	272

Proportional Free Cash Flow for the three months ended March 31, 2016, compared to the three months ended March 31, 2015, increased $81 million, due to the drivers above, partially offset by a $1 million increase in maintenance capital expenditures and adjusted for the impact of noncontrolling interest.

MCAC SBU

The following table summarizes Operating Cash Flow and Proportional Free Cash Flow (in millions) for our MCAC SBU for the periods indicated:



	Three Months Ended March 31,
Calculation of Proportional Free Cash Flow	2016			2015			$ Change
Net Cash Provided by Operating Activities	$	39		$	162		$	(123	)
Less: proportional adjustment factor on operating cash activities	(6		)	(33		)	27
Proportional Adjusted Operating Cash Flow	33			129			(96		)
Less: proportional maintenance capital expenditures, net of reinsurance proceeds	(20		)	(15		)	(5		)
Proportional Free Cash Flow	$	13		$	114		$	(101	)

Operating Cash Flow for the three months ended March 31, 2016, compared to the three months ended March 31, 2015, decreased $123 million, driven primarily by the following businesses (in millions):



MCAC SBU	Amount
Dominican Republic
Timing of collections from LNG sales and distribution companies in the prior year	$	(34	)
Higher income tax payments due timing as well as payment of withholding taxes on prior year dividends	(31		)
Timing of annual property insurance premium payments to Corporate due to start of policy moving to calendar year	(9		)
Other	(5		)
Total Dominican Republic Decrease	(79		)
Panama
Lower compensation collections from government	(13		)
Higher energy and fuel purchases	(15		)
Higher collections from energy sales	17
Other	(5		)
Total Panama Decrease	(16		)
Puerto Rico
Lower collections from off-taker	(25		)
Other	9
Total Puerto Rico Decrease	(16		)
Other business drivers	(12		)
Total MCAC Operating Cash Decrease	$	(123	)

Proportional Free Cash Flow for the three months ended March 31, 2016, compared to the three months ended March 31, 2015, decreased $101 million, due to the drivers above, as well as a $5 million increase in maintenance capital expenditures and adjusted for the impact of noncontrolling interest.

EUROPE SBU

The following table summarizes Operating Cash Flow and Proportional Free Cash Flow (in millions) for our Europe SBU for the periods indicated:



	Three Months Ended March 31,
Calculation of Proportional Free Cash Flow	2016			2015			$ Change
Net Cash Provided by Operating Activities	$	92		$	153		$	(61	)
Less: proportional adjustment factor on operating cash activities	(6		)	(7		)	1
Proportional Adjusted Operating Cash Flow	86			146			(60		)
Less: proportional maintenance capital expenditures, net of reinsurance proceeds	(4		)	(7		)	3
Less: proportional non-recoverable environmental capital expenditures	(6		)	—			(6		)
Proportional Free Cash Flow	$	76		$	139		$	(63	)

Operating Cash Flow for the three months ended March 31, 2016, compared to the three months ended March 31, 2015, decreased $61 million, driven primarily by the following businesses (in millions):



Europe SBU	Amount
Maritza
Higher payments to fuel suppliers	$	(21	)
Total Maritza Decrease	(21		)
Kilroot
Lower operating margin primarily due to lower coal/gas spread and lower dispatch	(5		)
Higher tax payments due to current year payment for tax dispute as well as a prior year tax refund	(7		)
Other	(3		)
Total Kilroot Decrease	(15		)
Ballylumford
Timing of collections from off-taker received in the prior year	(16		)
Other	2
Total Ballylumford Decrease	(14		)
Other business drivers	(11		)
Total Europe SBU Operating Cash Decrease	$	(61	)

Proportional Free Cash Flow for the three months ended March 31, 2016, compared to the three months ended March 31, 2015, decreased $63 million, due to the drivers above, as well as a $3 million net increase in maintenance and non-recoverable capital expenditures and adjusted for the impact of noncontrolling interest.

ASIA SBU

The following table summarizes Operating Cash Flow and Proportional Free Cash Flow (in millions) for our Asia SBU for the periods indicated:



	Three Months Ended March 31,
Calculation of Proportional Free Cash Flow	2016			2015			$ Change
Net Cash Provided by Operating Activities	$	72		$	(2	)	$	74
Add: capital expenditures related to service concession assets ⁽¹⁾	24			20			4
Adjusted Operating Cash Flow	96			18			78
Less: proportional adjustment factor on operating cash activities ⁽²⁾	(48		)	(12		)	(36		)
Proportional Adjusted Operating Cash Flow	48			6			42
Less: proportional maintenance capital expenditures, net of reinsurance proceeds	(5		)	(2		)	(3		)
Proportional Free Cash Flow	$	43		$	4		$	39

⁽¹⁾Service concession asset expenditures excluded from proportional free cash flow non-GAAP metric.

⁽²⁾ Includes proportional adjustment amount for service concession asset expenditures of $12 million and $10 million for the three months ended March 31, 2016 and 2015, respectively.

Operating Cash Flow for the three months ended March 31, 2016, compared to the three months ended March 31, 2015, increased $74 million, driven primarily by the following businesses (in millions):



Asia SBU	Amount
Mong Duong
Additional operating cash received as plant was fully operational in 2016	$	31
Favorable impact from prior year initial working capital funding requirements for Mong Duong plant operations	36
Other	(2		)
Total Mong Duong Increase	65
Other business drivers	9
Total Asia SBU Operating Cash Increase	$	74

Proportional Free Cash Flow for the three months ended March 31, 2016, compared to the three months ended March 31, 2015, increased $39 million, due to the drivers above, partially offset by a $3 million increase in maintenance capital expenditures and adjusted for the impact of noncontrolling interest, as well as $2 million increase in proportional service concession assets, which was excluded from the calculation of proportional free cash flow.

CORPORATE

The following table summarizes Operating Cash Flow and Proportional Free Cash Flow ($ in millions) for Corporate for the periods indicated:



	Three Months Ended March 31,
Calculation of Proportional Free Cash Flow	2016			2015			$ Change
Net Cash Used by Operating Activities	$	(49	)	$	(117	)	$	68
Proportional Adjusted Operating Cash Flow	(49		)	(117		)	68
Less: proportional maintenance capital expenditures, net of reinsurance proceeds	(1		)	—			(1		)
Proportional Free Cash Flow	$	(50	)	$	(117	)	$	67

Operating Cash Flow for the three months ended March 31, 2016, compared to the three months ended March 31, 2015, increased $68 million, driven primarily by the following businesses (in millions):



Corporate	Amount
Timing of annual property insurance premiums received from SBUs due to start of policy changed to calendar year	$	80
Lower interest payments due principal repayments on debt	11
Higher payments for people-related costs primarily due to inflation and severance	(9		)
Less cash received due to lower volume and value of foreign currency derivatives	(9		)
Other	(5		)
Total	$	68

Proportional Free Cash Flow for the three months ended March 31, 2016, compared to the three months ended March 31, 2015, increased $67 million, due to the drivers above, partially offset by a $1 million increase in maintenance capital expenditures.

Parent Company Liquidity

The following Parent Company Liquidity discussion is included as a useful measure of the liquidity available to The AES Corporation, or the Parent Company, given the non-recourse nature of most of our indebtedness. Parent Company Liquidity as outlined below is a non-GAAP measure and should not be construed as an alternative to cash and cash equivalents which are determined in accordance with GAAP as a measure of liquidity, and are disclosed in the Condensed Consolidated Statements of Cash Flows. Parent Company Liquidity may differ from similarly titled measures used by other companies.

The principal sources of liquidity at the Parent Company level are dividends and other distributions from our subsidiaries, including refinancing proceeds; proceeds from debt and equity financings at the Parent Company level, including availability under our credit facility; and proceeds from asset sales.

Cash requirements at the Parent Company level are primarily to fund interest; principal repayments of debt; acquisitions; construction commitments; other equity commitments; common stock repurchases and dividends; taxes; and Parent Company overhead and development costs.

The Company defines Parent Company Liquidity as cash available to the Parent Company plus available borrowings under existing credit facility. The cash held at qualified holding companies represents cash sent to subsidiaries of the Company domiciled outside of the U.S. Such subsidiaries have no contractual restrictions on their ability to send cash to the Parent Company. Parent Company Liquidity is reconciled to its most directly comparable GAAP financial measure, cash and cash equivalents, at the periods indicated as follows (in millions):



	March 31, 2016			December 31, 2015
Consolidated cash and cash equivalents	$	1,185		$	1,262
Less: Cash and cash equivalents at subsidiaries	(1,168		)	(862		)
Parent and qualified holding companies’ cash and cash equivalents	17			400
Commitments under Parent credit facilities	800			800
Less: Letters of credit under the credit facilities	(62		)	(62		)
Less: Borrowings under the credit facilities	(80		)	—
Borrowings available under Parent credit facilities	658			738
Total Parent Company Liquidity	$	675		$	1,138

The Company paid a dividend of $0.11 per share to its common stockholders during the three months ended March 31, 2016. While we intend to continue payment of dividends and believe we will have sufficient liquidity to do so, we can provide no assurance that we will continue to pay dividends, or if continued, the amount of such dividends.

Recourse Debt

Our total recourse debt was $4.9 billion and $5.0 billion as of March 31, 2016 and December 31, 2015, respectively. See Note 7—Debt in Item 1.—Financial Statements of this Form 10-Q and Note 12—Debt in Item 8.—Financial Statements and Supplementary Data of our 2015 Form 10-K for additional detail.

While we believe that our sources of liquidity will be adequate to meet our needs for the foreseeable future, this belief is based on a number of material assumptions, including, without limitation, assumptions about our ability to access the capital markets (see Key Trends and Uncertainties in Item 2), the operating and financial performance of our subsidiaries, currency exchange rates, power market pool prices, and the ability of our subsidiaries to pay dividends. In addition, our subsidiaries’ ability to declare and pay cash dividends to us (at the Parent Company level) is subject to certain limitations contained in loans, governmental provisions and other agreements. We can provide no assurance that these sources will be available when needed or that the actual cash requirements will not be greater than anticipated. We have met our interim needs for shorter-term and working capital financing at the Parent Company level with our senior secured credit facility. See Item 1A.—Risk Factors—The AES Corporation is a holding company and its ability to make payments on its outstanding indebtedness, including its public debt securities, is dependent upon the receipt of funds from its subsidiaries by way of dividends, fees, interest, loans or otherwise of the Company’s 2015 Form 10-K.

Various debt instruments at the Parent Company level, including our senior secured credit facility, contain certain restrictive covenants. The covenants provide for — among other items — limitations on other indebtedness, liens, investments and guarantees; limitations on dividends, stock repurchases and other equity transactions; restrictions and limitations on mergers and acquisitions, sales of assets, leases, transactions with affiliates and off-balance sheet and derivative arrangements; maintenance of certain financial ratios; and financial and other reporting requirements.

As of March 31, 2016, we were in compliance with these covenants at the Parent Company level.

Non-Recourse Debt

While the lenders under our non-recourse debt financings generally do not have direct recourse to the Parent Company, defaults thereunder can still have important consequences for our results of operations and liquidity, including, without limitation:


•	Reducing our cash flows as the subsidiary will typically be prohibited from distributing cash to the Parent Company during the time period of any default;


•	Triggering our obligation to make payments under any financial guarantee, letter of credit or other credit support we have provided to or on behalf of such subsidiary;


•	Causing us to record a loss in the event the lender forecloses on the assets; and


•	Triggering defaults in our outstanding debt at the Parent Company.

For example, our senior secured credit facility and outstanding debt securities at the Parent Company include events of default for certain bankruptcy-related events involving material subsidiaries. In addition, our senior secured credit facility at the Parent Company includes events of default related to payment defaults and accelerations of outstanding debt of material subsidiaries.

Some of our subsidiaries are currently in default with respect to all or a portion of their outstanding indebtedness. The total non-recourse debt classified as current in the accompanying Condensed Consolidated Balance Sheets amounts to $2.2 billion. The portion of current debt related to such defaults was $695 million at March 31, 2016, all of which was non-recourse debt related to three subsidiaries — Maritza, Kavarna and Sogrinsk. See Note 7—Debt in Item 1.—Financial Statements of this Form 10-Q for additional detail.

None of the subsidiaries that are currently in default are subsidiaries that met the applicable definition of materiality under AES’ corporate debt agreements as of March 31, 2016, in order for such defaults to trigger an event of default or permit acceleration under AES’ indebtedness. However, as a result of additional dispositions of assets, other significant reductions in asset carrying values or other matters in the future that may impact our financial position and results of operations or the financial position of the individual subsidiary, it is possible that one or more of these subsidiaries could fall within the definition of a “material subsidiary” and thereby upon an acceleration trigger an event of default and possible acceleration of the indebtedness under the Parent Company’s outstanding debt securities. A material subsidiary is defined in the Company’s senior secured credit facility as any business that contributed 20% or more of the Parent Company’s total cash distributions from businesses for the four most recently ended fiscal quarters. As of March 31, 2016, none of the defaults listed above individually or in the aggregate results in or is at risk of triggering a cross-default under the recourse debt of the Company.

Critical Accounting Policies and Estimates

The condensed consolidated financial statements of AES are prepared in conformity with U.S. GAAP, which requires the use of estimates, judgments and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the periods

presented. The Company’s significant accounting policies are described in Note 1—General and Summary of Significant Accounting Policies of our 2015 Form 10-K. The Company’s critical accounting estimates are described in Management’s Discussion and Analysis of Financial Condition and Results of Operations in the 2015 Form 10-K. An accounting estimate is considered critical if the estimate requires management to make an assumption about matters that were highly uncertain at the time the estimate was made, different estimates reasonably could have been used, or if changes in the estimate that would have a material impact on the Company’s financial condition or results of operations are reasonably likely to occur from period to period. Management believes that the accounting estimates employed are appropriate and resulting balances are reasonable; however, actual results could differ from the original estimates, requiring adjustments to these balances in future periods. The Company has reviewed and determined that these remain as critical accounting policies as of and for the three months ended March 31, 2016.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Overview Regarding Market Risks — Our generation and utility businesses are exposed to and proactively manage market risk. Our primary market risk exposure is to the price of commodities, particularly electricity, oil, natural gas, coal and environmental credits. We operate in multiple countries and as such are subject to volatility in exchange rates at varying degrees at the subsidiary level and between our functional currency, the U.S. Dollar, and currencies of the countries in which we operate. We are also exposed to interest rate fluctuations due to our issuance of debt and related financial instruments.

The disclosures in this Item 3 are based upon a number of assumptions; actual effects may differ. The safe harbor provided in Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934 shall apply to the disclosures contained in this Item 3. For further information regarding market risk, see Item 1A.—Risk Factors, Our financial position and results of operations may fluctuate significantly due to fluctuations in currency exchange rates experienced at our foreign operations; Our businesses may incur substantial costs and liabilities and be exposed to price volatility as a result of risks associated with the wholesale electricity markets, which could have a material adverse effect on our financial performance; and We may not be adequately hedged against our exposure to changes in commodity prices or interest rates of the 2015 Form 10-K.

Commodity Price Risk — Although we prefer to hedge our exposure to the impact of market fluctuations in the price of electricity, fuels and environmental credits, some of our generation businesses operate under short-term sales or under contract sales that leave an un-hedged exposure on some of our capacity or through imperfect fuel pass-throughs. In our utility businesses, we may be exposed to commodity price movements depending on our excess or shortfall of generation relative to load obligations and sharing or pass-through mechanisms. These businesses subject our operational results to the volatility of prices for electricity, fuels and environmental credits in competitive markets. We employ risk management strategies to hedge our financial performance against the effects of fluctuations in energy commodity prices. The implementation of these strategies can involve the use of physical and financial commodity contracts, futures, swaps and options.

When hedging the output of our generation assets, we utilize contract strategies that lock in the spread per MWh between variable costs and the price at which the electricity can be sold. The portion of our sales and purchases that are not subject to such agreements or contracted businesses where indexation is not perfectly matched to business drivers will be exposed to commodity price risk.

AES businesses will see changes in variable margin performance as global commodity prices shift. We have entered into hedges to partially mitigate the exposure of variable margin to commodity moves. As of March 31, 2016, the portfolio’s adjusted pretax earnings exposure for the remainder of 2016 to a 10% move in commodity prices would be approximately $15 million for U.S. power (DPL), and less than $5 million for natural gas, $5 million for oil and $10 million for coal. Our estimates exclude correlation of oil with coal or natural gas. For example, a decline in oil or natural gas prices can be accompanied by a decline in coal price if commodity prices are correlated. In aggregate, the Company’s downside exposure occurs with lower oil, lower natural gas, and higher coal prices. Exposures at individual businesses will change as new contracts or financial hedges are executed, and our sensitivity to changes in commodity prices generally increases in later years with reduced hedge levels at some of our businesses.

Commodity prices affect our businesses differently depending on the local market characteristics and risk management strategies. Spot power prices, contract indexation provisions and generation costs can be directly or indirectly affected by movements in the price of natural gas, oil and coal. We have some natural offsets across our businesses such that low commodity prices may benefit certain businesses and be a cost to others. Exposures are not perfectly linear or symmetric. The sensitivities are affected by a number of local or indirect market factors. Examples of these factors include hydrology, local energy market supply/demand balances, regional fuel supply

issues, regional competition, bidding strategies and regulatory interventions such as price caps. Operational flexibility changes the shape of our sensitivities. For instance, certain power plants may limit downside exposure by reducing dispatch in low market environments. Volume variation also affects our commodity exposure. The volume sold under contracts or retail concessions can vary based on weather and economic conditions resulting in a higher or lower volume of sales in spot markets. Thermal unit availability and hydrology can affect the generation output available for sale and can affect the marginal unit setting power prices.

In the US SBU, the generation businesses are largely contracted but may have residual risk to the extent contracts are not perfectly indexed to the business drivers. IPL sells power at wholesale once retail demand is served, so retail sales demand may affect commodity exposure. Additionally, at DPL, open access allows our retail customers to switch to alternative suppliers; falling energy prices may increase the rate of switching; DPL sells generation in excess of its retail demand under short-term sales. Given that natural gas-fired generators set power prices for many markets, higher natural gas prices expand margins. The positive impact on margins will be moderated if natural gas-fired generators set the market price only during some periods.

In the Andes SBU, our business in Chile owns assets in the central and northern regions of the country and has a portfolio of contract sales in both. In the central region, the contract sales generally cover the efficient generation from our coal-fired and hydroelectric assets. Any residual spot price risk will primarily be driven by the amount of hydrological inflows. In the case of low hydroelectric generation, spot price exposure is capped by the ability to dispatch our natural gas/diesel assets, the price of which depends on fuel pricing at the time required. There is a small amount of coal generation in the northern region that is not covered by the portfolio of contract sales and therefore subject to spot price risk. In both regions, generators with oil or oil-linked fuel generally set power prices. In Colombia, we operate under a short-term sales strategy and have commodity exposure to unhedged volumes. Because we own hydroelectric assets there, contracts are not indexed to fuel.

In the Brazil SBU, the hydroelectric generating facility is covered by contract sales. Under normal hydrological volatility, spot price risk is mitigated through a regulated sharing mechanism across all hydroelectric generators in the country. Under drier conditions, the sharing mechanism may not be sufficient to cover the business’ contract position, and therefore it may have to purchase power at spot prices driven by the cost of thermal generation.

In the MCAC SBU, our businesses have commodity exposure on unhedged volumes. Panama is highly contracted under a portfolio of fixed volume contract sales. To the extent hydrological inflows are greater than or less than the contract sales volume, the business will be sensitive to changes in spot power prices which may be driven by oil prices in some time periods. In the Dominican Republic, we own natural gas-fired assets contracted under a portfolio of contract sales and a coal-fired asset contracted with a single contract, and both contract and spot prices may move with commodity prices. Additionally, the contract levels do not always match our generation availability and our assets may be sellers of spot prices in excess of contract levels or a net buyer in the spot market to satisfy contract obligations.

In the Europe SBU, our Kilroot facility operates on a short-term sales strategy. To the extent that sales are unhedged, the commodity risk at our Kilroot business is to the clean dark spread — the difference between electricity price and our coal-based variable dispatch cost including emissions. Natural gas-fired generators set power prices for many periods, so higher natural gas prices generally expand margins and higher coal or emissions prices reduce them. Similarly, increased wind generation displaces higher cost generation, reducing Kilroot’s margins, and vice versa.

In the Asia SBU, our Masinloc business is a coal-fired generation facility which hedges its output under a portfolio of contract sales that are indexed to fuel prices, with generation in excess of contract volume or shortfalls of generation relative to contract volumes settled in the spot market. Low oil prices may be a driver of margin compression since oil affects spot power sale prices. Our Mong Duong business has minimal exposure to commodity price risk as it has no merchant exposure and fuel is subject to a pass-through mechanism.

Foreign Exchange Rate Risk — In the normal course of business, we are exposed to foreign currency risk and other foreign operations risks that arise from investments in foreign subsidiaries and affiliates. A key component of these risks stems from the fact that some of our foreign subsidiaries and affiliates utilize currencies other than our consolidated reporting currency, the U.S. Dollar. Additionally, certain of our foreign subsidiaries and affiliates have entered into monetary obligations in the U.S. Dollar or currencies other than their own functional currencies. We have varying degrees of exposure to changes in the exchange rate between the U.S. Dollar and the following currencies: Argentine Peso, Brazilian Real, British Pound, Chilean Peso, Colombian Peso, Dominican Peso, Euro, Indian Rupee, Kazakhstani Tenge, Mexican Peso and Philippine Peso. These subsidiaries and affiliates have attempted to limit potential FX exposure by entering into revenue contracts that adjust to changes in FX rates. We

also use foreign currency forwards, swaps and options, where possible, to manage our risk related to certain foreign currency fluctuations.

We have entered into hedges to partially mitigate the exposure of earnings translated into the U.S. Dollar to foreign exchange volatility. The largest FX risks over a 12-month forward-looking period stem from the following currencies: Argentine Peso, British Pound, Brazilian Real, Colombian Peso, Euro and Kazakhstani Tenge. As of March 31, 2016, assuming a 10% U.S. Dollar appreciation, adjusted pretax earnings attributable to foreign subsidiaries exposed to movement in the exchange rate of the Argentine Peso and Colombian Peso are projected to be reduced by $5 million for each currency for the remainder of 2016. The Brazilian Real, Kazakhstani Tenge, Euro and British Pound impacts are projected to be less than $5 million for each currency for the remainder of 2016. These numbers have been produced by applying a one-time 10% U.S. Dollar appreciation to forecasted exposed pretax earnings for 2016 coming from the respective subsidiaries exposed to the currencies listed above, net of the impact of outstanding hedges and holding all other variables constant. The numbers presented above are net of any transactional gains/losses. These sensitivities may change in the future as new hedges are executed or existing hedges are unwound. Additionally, updates to the forecasted pretax earnings exposed to FX risk may result in further modification. The sensitivities presented do not capture the impacts of any administrative market restrictions or currency inconvertibility.

Interest Rate Risks — We are exposed to risk resulting from changes in interest rates as a result of our issuance of variable and fixed-rate debt, as well as interest rate swap, cap and floor and option agreements.

Decisions on the fixed-floating debt ratio are made to be consistent with the risk factors faced by individual businesses or plants. Depending on whether a plant’s capacity payments or revenue stream is fixed or varies with inflation, we partially hedge against interest rate fluctuations by arranging fixed-rate or variable-rate financing. In certain cases, particularly for non-recourse financing, we execute interest rate swap, cap and floor agreements to effectively fix or limit the interest rate exposure on the underlying financing. Most of our interest rate risk is related to non-recourse financings at our businesses.

As of March 31, 2016, the portfolio’s pretax earnings exposure for the remainder of 2016 to a 100-basis-point increase in interest rates for our Argentine Peso, Brazilian Real, Colombian Peso, Euro, Kazakhstani Tenge and U.S. Dollar denominated debt would be approximately $20 million based on the impact of a one time, 100-basis-point upward shift in interest rates on interest expense for the debt denominated in these currencies. The amounts do not take into account the historical correlation between these interest rates.

ITEM 4. CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and Procedures — The Company, under the supervision and with the participation of its management, including the Company’s CEO and Chief Financial Officer (“CFO”), evaluated the effectiveness of its “disclosure controls and procedures,” as such term is defined in Rule 13a-15(e) under the Securities Act of 1934, as amended (the “Exchange Act”), as of the end of the period covered by this Quarterly Report on Form 10-Q. Based on that evaluation, our CEO and CFO have concluded that our disclosure controls and procedures were effective as of March 31, 2016, to ensure that information required to be disclosed by the Company in reports that we file or submit under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in SEC rules and forms, and include controls and procedures designed to ensure that information required to be disclosed by us in such reports is accumulated and communicated to our management, including our CEO and CFO, as appropriate, to allow timely decisions regarding required disclosures.

Changes in Internal Controls over Financial Reporting — There were no changes that occurred during the fiscal quarter covered by this Quarterly Report on Form 10-Q that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

PART II: OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

The Company is involved in certain claims, suits and legal proceedings in the normal course of business. The Company has accrued for litigation and claims where it is probable that a liability has been incurred and the amount of loss can be reasonably estimated. The Company believes, based upon information it currently possesses and taking into account established reserves for estimated liabilities and its insurance coverage, that the ultimate outcome of these proceedings and actions is unlikely to have a material adverse effect on the Company's financial statements. It is reasonably possible, however, that some matters could be decided unfavorably to the Company and could require the Company to pay damages or make expenditures in amounts that could be material but cannot be estimated as of March 31, 2016.

In 1989, Centrais Elétricas Brasileiras S.A. (“Eletrobrás”) filed suit in the Fifth District Court in the state of Rio de Janeiro (“FDC”) against Eletropaulo Eletricidade de São Paulo S.A. (“EEDSP”) relating to the methodology for calculating monetary adjustments under the parties' financing agreement. In April 1999, the FDC found for Eletrobrás and in September 2001, Eletrobrás initiated an execution suit in the FDC to collect approximately R$1.85 billion ($509 million) from Eletropaulo as estimated by Eletropaulo (or approximately R$2.38 billion ($655 million) plus legal costs according to Eletrobrás as of December 2015) and a lesser amount from an unrelated company, Companhia de Transmissão de Energia Elétrica Paulista (“CTEEP”) (Eletropaulo and CTEEP were spun off of EEDSP pursuant to its privatization in 1998). In November 2002, the FDC rejected Eletropaulo's defenses in the execution suit. On appeal, the case was remanded to the FDC for further proceedings to determine whether Eletropaulo is liable for the debt. In December 2012, the FDC issued a decision that Eletropaulo is liable for the debt. However, that decision was annulled on appeal and the case was remanded to the FDC for further proceedings. On remand at the FDC, the FDC appointed an accounting expert to analyze the issues in the case. In September 2015, the expert issued a preliminary report that concluded that Eletropaulo is liable for the debt, without quantifying the debt. Eletropaulo has submitted questions to the expert and reports rebutting the expert's preliminary report. The expert may issue a final report in the near future. Ultimately, a decision will be issued by the FDC, which will be free to reject or adopt in whole or in part the expert's report. If the FDC again determines that Eletropaulo is liable for the debt, Eletrobrás will be entitled to resume the execution suit in the FDC. If Eletrobrás does so, after the amount of the alleged debt is determined, Eletropaulo will be required to provide security for its alleged liability. In that case, if Eletrobrás requests the seizure of such security and the FDC grants such request, Eletropaulo's results of operations may be materially adversely affected and, in turn, the Company's results of operations could be materially adversely affected. In addition, in February 2008, CTEEP filed a lawsuit in the FDC against Eletrobrás and Eletropaulo seeking a declaration that CTEEP is not liable for any debt under the financing agreement. Eletropaulo believes it has meritorious defenses to the claims asserted against it and will defend itself vigorously in these proceedings; however, there can be no assurances that it will be successful in its efforts.

In September 1996, a public civil action was asserted against Eletropaulo and Associação Desportiva Cultural Eletropaulo (the “Associação”) relating to alleged environmental damage caused by construction of the Associação near Guarapiranga Reservoir. The initial decision that was upheld by the Appellate Court of the state of São Paulo in 2006 found that Eletropaulo should repair the alleged environmental damage by demolishing certain construction and reforesting the area, and either sponsor an environmental project which would cost approximately R$1.8 million ($496 thousand) as of December 31, 2015, or pay an indemnification amount of approximately R$15 million ($4 million). Eletropaulo has appealed this decision to the Supreme Court and the Supreme Court affirmed the decision of the Appellate Court. Following the Supreme Court's decision, the case has been remanded to the court of first instance for further proceedings and to monitor compliance by the defendants with the terms of the decision. In January 2014, Eletropaulo informed the court that it intended to comply with the court's decision by donating a green area inside a protection zone and restore watersheds, the aggregate cost of which is expected to be approximately R$1.8 million ($496 thousand). Eletropaulo also requested that the court add the current owner of the land where the Associação facilities are located, Empresa Metropolitana de Águas e Energia S.A. (“EMAE”), as a party to the lawsuit and order EMAE to perform the demolition and reforestation aspects of the court's decision. In July 2014, the court requested the Secretary of the Environment for the State of São Paulo to notify the court of its opinion regarding the acceptability of the green areas to be donated by Eletropaulo to the State of São Paulo. In January 2015, the Secretary of the Environment for the State of São Paulo notified Eletropaulo and the court that it would not accept Eletropaulo's proposed green areas donation. Instead of such green areas donation, the Secretary of the Environment proposed in March 2015 that Eletropaulo undertake an environmental project to offset the alleged environmental damage. Since March 2015, Eletropaulo and the Secretary of Environment have been working together to define an environmental project, which will be submitted for approval by the Public Prosecutor. The cost of such project is currently estimated to be R$2 million ($551 thousand).

In December 2001, Gridco Ltd. (“Gridco”) served a notice to arbitrate pursuant to the Indian Arbitration and Conciliation Act of 1996 on the Company, AES Orissa Distribution Private Limited (“AES ODPL”), and Jyoti Structures (“Jyoti”) pursuant to the terms of the shareholders agreement between Gridco, the Company, AES ODPL, Jyoti and the Central Electricity Supply Company of Orissa Ltd. (“CESCO”), an affiliate of the Company. In the arbitration, Gridco asserted that a comfort letter issued by the Company in connection with the Company's indirect investment in CESCO obligates the Company to provide additional financial support to cover all of CESCO's financial obligations to Gridco. Gridco appeared to be seeking approximately $189 million in damages, plus undisclosed penalties and interest, but a detailed alleged damage analysis was not filed by Gridco. The Company counterclaimed against Gridco for damages. In June 2007, a 2-to-1 majority of the arbitral tribunal rendered its award rejecting Gridco's claims and holding that none of the respondents, the Company, AES ODPL, or Jyoti, had any liability to Gridco. The respondents' counterclaims were also rejected. A majority of the tribunal later awarded the respondents, including the Company, some of their costs relating to the arbitration. Gridco filed challenges of the tribunal's awards with the local Indian court. Gridco's challenge of the costs award has been dismissed by the court, but its challenge of the liability award remains pending. The Company believes that it has meritorious defenses to the claims asserted against it and will defend itself vigorously in these proceedings; however, there can be no assurances that it will be successful in its efforts.

In March 2003, the office of the Federal Public Prosecutor for the State of São Paulo, Brazil (“MPF”) notified Eletropaulo that it had commenced an inquiry into the BNDES financings provided to AES Elpa and AES Transgás, the rationing loan provided to Eletropaulo, changes in the control of Eletropaulo, sales of assets by Eletropaulo, and the quality of service provided by Eletropaulo to its customers. The MPF requested various documents from Eletropaulo relating to these matters. In July 2004, the MPF filed a public civil lawsuit in the Federal Court of São Paulo (“FCSP”) alleging that BNDES violated Law 8429/92 (“the Administrative Misconduct Act”) and BNDES's internal rules by (1) approving the AES Elpa and AES Transgás loans; (2) extending the payment terms on the AES Elpa and AES Transgás loans; (3) authorizing the sale of Eletropaulo's preferred shares at a stock-market auction; (4) accepting Eletropaulo's preferred shares to secure the loan provided to Eletropaulo; and (5) allowing the restructurings of Light Serviços de Eletricidade S.A. and Eletropaulo. The MPF also named AES Elpa and AES Transgás as defendants in the lawsuit because they allegedly benefited from BNDES's alleged violations. In May 2006, the FCSP ruled that the MPF could pursue its claims based on the first, second, and fourth alleged violations noted above. The MPF subsequently filed an interlocutory appeal with the Federal Court of Appeals (“FCA”) seeking to require the FCSP to consider all five alleged violations. In April 2015, the FCA issued a decision holding that the FCSP should consider all five alleged violations. AES Elpa and AES Brasiliana (the successor of AES Transgás) have appealed to the Superior Court of Justice. The lawsuit remains pending before the FCSP. AES Elpa and AES Brasiliana believe they have meritorious defenses to the allegations asserted against them and will defend themselves vigorously in these proceedings; however, there can be no assurances that they will be successful in their efforts.

Pursuant to their environmental audit, AES Sul and AES Florestal discovered 200 barrels of solid creosote waste and other contaminants at a pole factory that AES Florestal had been operating. The conclusion of the audit was that a prior operator of the pole factory, Companhia Estadual de Energia (“CEEE”), had been using those contaminants to treat the poles that were manufactured at the factory. On their initiative, AES Sul and AES Florestal communicated with Brazilian authorities and CEEE about the adoption of containment and remediation measures. In March 2008, the State Attorney of the state of Rio Grande do Sul, Brazil filed a public civil action against AES Sul, AES Florestal and CEEE seeking an order requiring the companies to recover the contaminated area located on the grounds of the pole factory and an indemnity payment of approximately R$6 million ($2 million) to the state's Environmental Fund. In October 2011, the State Attorney Office filed a request for an injunction ordering the defendant companies to contain and remove the contamination immediately. The court granted injunctive relief on October 18, 2011, but determined only that defendant CEEE was required to proceed with the removal work. In May 2012, CEEE began the removal work in compliance with the injunction. The removal costs are estimated to be approximately R$60 million ($17 million) and the work was completed in February 2014. In parallel with the removal activities, a court-appointed expert investigation took place, which was concluded in May 2014. The court-appointed expert final report was presented to the State Attorneys in October 2014, and in January 2015 to the defendant companies. In March 2015, AES Sul and AES Florestal submitted comments and supplementary questions regarding the expert report. The Company believes that it has meritorious defenses to the claims asserted against it and will defend itself vigorously in these proceedings; however, there can be no assurances that it will be successful in its efforts.

In March 2009, AES Uruguaiana Empreendimentos S.A. (“AESU”) in Brazil initiated arbitration in the ICC against YPF S.A. (“YPF”) seeking damages and other relief relating to YPF's breach of the parties' gas supply agreement (“GSA”). Thereafter, in April 2009, YPF initiated arbitration in the ICC against AESU and two unrelated

parties, Companhia de Gas do Estado do Rio Grande do Sul and Transportador de Gas del Mercosur S.A. (“TGM”), claiming that AESU wrongfully terminated the GSA and caused the termination of a transportation agreement (“TA”) between YPF and TGM (“YPF Arbitration”). YPF sought an unspecified amount of damages from AESU, a declaration that YPF's performance was excused under the GSA due to certain alleged force majeure events, or, in the alternative, a declaration that the GSA and the TA should be terminated without a finding of liability against YPF because of the allegedly onerous obligations imposed on YPF by those agreements. In addition, in the YPF Arbitration, TGM asserted that if it was determined that AESU was responsible for the termination of the GSA, AESU was liable for TGM's alleged losses, including losses under the TA. In April 2011, the arbitrations were consolidated into a single proceeding. The hearing on liability issues took place in December 2011. In May 2013, the arbitral tribunal issued a liability award in AESU's favor. YPF thereafter challenged the award in Argentine court. In December 2015, an Argentine court issued a decision purporting to annul the liability award. AESU has appealed to the Supreme Court of Argentina. The damages hearing in the arbitration took place on November 16-17, 2015. In April 2016, the tribunal issued a damages award in AESU’s favor. YPF may attempt to challenge the damages award. AESU believes it has meritorious claims and defenses and will assert them vigorously; however, there can be no assurances that it will be successful in its efforts.

In October 2009, AES Mérida III, S. de R.L. de C.V. (“AES Mérida”), one of our businesses in Mexico, initiated arbitration against its fuel supplier and electricity offtaker, Comisión Federal de Electricidad (“CFE”), seeking a declaration that CFE breached the parties' PPA by supplying gas that did not comply with the PPA's specifications. Alternatively, AES Mérida requested a declaration that the supply of such gas by CFE is a force majeure event under the PPA. CFE disputed the claims. Although it did not assert counterclaims, in its closing brief CFE asserted that it is entitled to a partial refund of the capacity charge payments that it made for power generated with the out-of-specification gas. In July 2012, the arbitral tribunal issued an award in AES Mérida's favor. In December 2012, CFE initiated an action in Mexican court seeking to nullify the award. AES Mérida opposed the request and asserted a counterclaim to confirm the award. In February 2014, the court rejected CFE's claims and granted AES Mérida's request to confirm the award. CFE has appealed the court's decision. The appeal is pending before the Mexican Supreme Court. AES Mérida believes it has meritorious grounds to defeat that action; however, there can be no assurances that it will be successful.

In October 2009, IPL received a NOV and Finding of Violation from the EPA pursuant to the CAA Section 113(a). The NOV alleges violations of the CAA at IPL's three primarily coal-fired electric generating facilities dating back to 1986. The alleged violations primarily pertain to the Prevention of Significant Deterioration and nonattainment New Source Review requirements under the CAA. Since receiving the letter, IPL management has met with EPA staff regarding possible resolutions of the NOV. At this time, we cannot predict the ultimate resolution of this matter. However, settlements and litigated outcomes of similar cases have required companies to pay civil penalties, install additional pollution control technology on coal-fired electric generating units, retire existing generating units, and invest in additional environmental projects. A similar outcome in this case could have a material impact to IPL and could, in turn, have a material impact on the Company. IPL would seek recovery of any operating or capital expenditures related to air pollution control technology to reduce regulated air emissions; however, there can be no assurances that it would be successful in that regard.

In November 2009, April 2010, December 2010, April 2011, June 2011, August 2011, November 2011, and October 2014, substantially similar personal injury lawsuits were filed by a total of 50 residents and decedent estates in the Dominican Republic against the Company, AES Atlantis, Inc., AES Puerto Rico, LP, AES Puerto Rico, Inc., and AES Puerto Rico Services, Inc., in the Superior Court for the state of Delaware. In each lawsuit, the plaintiffs alleged that the coal combustion by-products of AES Puerto Rico's power plant were illegally placed in the Dominican Republic from October 2003 through March 2004 and subsequently caused the plaintiffs' birth defects, other personal injuries, and/or deaths. The plaintiffs did not quantify their alleged damages. The Superior Court subsequently stayed all lawsuits but the November 2009 lawsuit. In March 2016, the parties reached a settlement in principle to resolve all eight lawsuits and thereafter executed a definitive settlement agreement. In May 2016, the Superior Court approved the settlement.

On February 11, 2011, Eletropaulo received a notice of violation from São Paulo State's Environmental Authorities for allegedly destroying 0.32 hectares of native vegetation at the Conservation Park of Serra do Mar (“Park”), without previous authorization or license. The notice of violation asserted a fine of approximately R$1 million ($275 thousand) and the suspension of Eletropaulo activities in the Park. As a response to this administrative procedure before the São Paulo State Environmental Authorities (“São Paulo EA”), Eletropaulo timely presented its defense on February 28, 2011 seeking to vacate the NOV or reduce the fine. In December 2011, the São Paulo EA declined to vacate the NOV but reduced the fine to R$757 thousand ($208 thousand) and recognized the possibility of an additional 40% reduction of the fine if Eletropaulo agrees to recover the affected area with additional vegetation. Eletropaulo did not appeal the decision and discussed the terms of a possible settlement with

the São Paulo EA, including a plan to recover the affected area by primarily planting additional trees. In March 2012, the state of São Paulo Prosecutor's Office of São Bernardo do Campo initiated a Civil Proceeding to review the compliance by Eletropaulo with the terms of any possible settlement. The Park Administrator subsequently approved an area for the recovery project different from the affected area, which was no longer available. On January 23, 2015, AES Eletropaulo entered into a Recovery and Compensation Agreement with the Coordenadoria de Fiscalização Ambiental (“CFA”) to restore 3.2 hectares during the course of two years, which restoration is currently estimated to cost R$592 thousand ($152 thousand). AES completed the restoration of the area in June 2015, and will maintain such restored area until July 2017. In June 2015, the state of São Paulo Prosecutor’s Office of São Bernardo do Campo decided to close its Civil Proceeding, and the Superior Counsel of the Public Prosecutor’s Office has confirmed such closing. Upon completion of the recovery project, as approved and established in the Recovery and Compensation Agreement, AES will be entitled to a 40% reduction (R$303 thousand or $83 thousand) of the fine as legally provided.

In June 2011, the São Paulo Municipal Tax Authority (the “Tax Authority”) filed 60 tax assessments in São Paulo administrative court against Eletropaulo, seeking to collect services tax (“ISS”) that allegedly had not been paid on revenues for services rendered by Eletropaulo. Eletropaulo challenged the assessments on the ground that the revenues at issue were not subject to ISS. In October 2013, the First Instance Administrative Court determined that Eletropaulo was liable for ISS, interest, and related penalties totaling approximately R$3.3 billion ($908 million) as estimated by Eletropaulo. Eletropaulo thereafter appealed to the Second Instance Administrative Court (“SIAC”). In January 2016, the Tax Authority reduced the total amount of the ISS assessments to approximately R$243 million ($67 million). The reduced amount of ISS remains under consideration by the SIAC. No tax is due while the appeal is pending. Eletropaulo believes it has meritorious defenses and will defend itself vigorously in these proceedings; however, there can be no assurances that it will be successful in its efforts.

In January 2012, the Brazil Federal Tax Authority issued an assessment alleging that AES Tietê paid PIS and COFINS taxes from 2007 to 2010 at a lower rate than the tax authority believed was applicable. AES Tietê challenged the assessment on the ground that the tax rate was set in the applicable legislation. In April 2013, the First Instance Administrative Court determined that AES Tietê should have calculated the taxes at the higher rate and that AES Tietê was liable for unpaid taxes, interest and penalties totaling approximately R$923 million ($254 million) as estimated by AES Tietê. AES Tietê appealed to the SIAC. In January 2015, the SIAC issued a decision in AES Tietê's favor, finding that AES Tietê was not liable for unpaid taxes. The public prosecutor subsequently filed an appeal, which was denied as untimely. The Tax Authority thereafter filed a motion for clarification of the SIAC's decision, which motion remains pending. AES Tietê believes it has meritorious defenses to the claim and will defend itself vigorously in these proceedings; however, there can be no assurances that it will be successful in its efforts.

In August 2012, Fondo Patrimonial de las Empresas Reformadas (“FONPER”) (the Dominican instrumentality that holds the Dominican Republic's shares in Empresa Generadora de Electricidad Itabo, S.A. (“Itabo”)) filed a criminal complaint against certain current and former employees of AES. The criminal proceedings include a related civil component initiated against, among others, Coastal Itabo, Ltd. (“Coastal”) (the AES affiliate shareholder of Itabo) and New Caribbean Investment, S.A. (“NC”) (the AES affiliate that manages Itabo). FONPER asserts claims relating to the alleged mismanagement of Itabo and seeks approximately $270 million in damages. The Dominican District Attorney (“DA”) thereafter admitted the criminal complaint and requested that the Dominican Republic's Cámara de Cuentas (“Cámara”) perform an audit of the allegations in the criminal complaint. In October 2015, the Cámara issued its final report, determining that the contested actions of the AES employees were in accordance with Dominican law. Further, in August 2012, Coastal and NC initiated an international arbitration proceeding against FONPER and the Dominican Republic (“Respondents”), seeking a declaration that Coastal and NC have acted both lawfully and in accordance with the relevant contracts with the Respondents in relation to the management of Itabo. Coastal and NC also seek a declaration that the criminal complaint is a breach of the relevant contracts between the parties, including the obligation to arbitrate disputes. Coastal and NC further seek damages from the Respondents resulting from their breach of contract. The Respondents have denied the claims and challenged the jurisdiction of the arbitral tribunal. In February 2015, the Respondents made an application requesting that the tribunal rule on their jurisdictional objections prior to giving any consideration to the merits of the claims of Coastal and NC. In August 2015, the tribunal rejected the application. The tribunal has established the procedural schedule for the arbitration, but has not yet scheduled dates for the final evidentiary hearing. At the parties' request, the Tribunal has suspended the arbitration until July 30, 2016. The AES parties believe they have meritorious claims and defenses, which they will assert vigorously; however, there can be no assurances that they will be successful in their efforts.

In January 2015, DPL received NOVs from the EPA alleging violations of opacity at Stuart and Killen Stations, and in October 2015, IPL received a similar NOV alleging violations at Petersburg Station. In February 2016, IPL received an NOV from the EPA alleging violations of NSR and other CAA regulations, the Indiana SIP, and the Title

V operating permit at Petersburg Station. It is too early to determine whether the NOVs could have a material impact on our business, financial condition or results of our operations. We would seek recovery of any operating or capital expenditures for IPL, but not fines or penalties, related to air pollution control technology to reduce regulated air emissions; however, there can be no assurances that we would be successful in this regard.

In July 2015, BTG Pactual (“BTG”) initiated arbitration against AES Tietê under the parties' PPA. BTG claims that AES Tietê breached the PPA by purchasing more power than it was entitled to take under the PPA. BTG seeks to recover the payments that AES Tietê received from its spot-market sales of BTG's power, totaling approximately R$30 million ($8 million). BTG also seeks to terminate the PPA and to collect a termination payment of approximately R$560 million ($154 million). AES Tietê has placed R$30 million ($8 million) into escrow, with a full reservation of rights. AES Tietê has responded to the arbitration demand, contesting the claims against it. AES Tietê believes it has meritorious defenses to the claims asserted against it and will defend itself vigorously in this proceeding; however, there can be no assurances that it will be successful in its efforts.

In September 2015, AES Southland Development, LLC and AES Redondo Beach, LLC filed a lawsuit against the California Coastal Commission (the “CCC”) over the CCC's determination that the site of AES Redondo Beach included approximately 5.93 acres of CCC-jurisdictional wetlands. The CCC has asserted that AES Redondo Beach has improperly installed and operated water pumps affecting the alleged wetlands in violation of the California Coastal Act and Redondo Beach Local Coastal Program and has ordered AES Redondo Beach to restore the site. Additional potential outcomes of the CCC determination could include an order requiring AES Redondo Beach to fund a wetland mitigation project and/or pay fines or penalties. AES Redondo Beach believes that it has meritorious arguments and intends to vigorously prosecute such lawsuit, but there can be no assurances that it will be successful.

In October 2015, Ganadera Guerra, S.A. (“GG”) and Constructora Tymsa, S.A. (“CT”) filed separate lawsuits against AES Panama in the local courts of Panama. The claimants allege that AES Panama profited from a hydropower facility (La Estrella) being partially located on land owned first by GG and later by CT, and that AES Panama must pay compensation for its use of the land. The damages sought from AES Panama are approximately $680 million (GG) and $100 million (CT). AES Panama believes it has meritorious defenses to the claims asserted against it and will defend itself vigorously in the lawsuits; however, there can be no assurances that it will be successful in its efforts.

ITEM 1A. RISK FACTORS

There have been no material changes to the risk factors disclosed in Part I—Item 1A.—Risk Factors of our 2015 Form 10-K.

ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

The following table presents information regarding purchases made by The AES Corporation of its common stock:



Repurchase Period	Total Number of Shares Purchased	Average Price Paid Per Share		Total Number of Shares Repurchased as part of a Publicly Announced Purchase Plan ⁽¹⁾	Dollar Value of Maximum No. Of Shares To Be Purchased Under the Plan ⁽²⁾
1/1/2016 — 1/31/16	5,800,571	$	8.93	5,800,571	$	291,313,045
2/1/2016 — 2/29/16	2,886,412	9.35		2,886,412	264,351,513
3/1/2016 — 3/31/16	—	—		—	264,351,513
Total	8,686,983			8,686,983

_____________________________


⁽¹⁾	See Note 10—Equity—Stock Repurchase Program to the condensed consolidated financial statements in Item 1.—Financial Statements for further information.

⁽²⁾

The authorization permits the Company to repurchase stock through a variety of methods, including open market repurchases, purchases by contract (including, without limitation, accelerated stock repurchase programs or 10b5-1 plans) and/or privately negotiated transactions. There is no assurance as to the amount, timing or prices of repurchases, which may vary based on market conditions and other factors. The stock repurchase program may be modified, extended or terminated by the BoD at any time.

ITEM 3. DEFAULTS UPON SENIOR SECURITIES

None.

ITEM 4. MINE SAFETY DISCLOSURES

Not applicable.

ITEM 5. OTHER INFORMATION

None.

ITEM 6. EXHIBITS



31.1		Rule13a-14(a)/15d-14(a) Certification of Andrés Gluski (filed herewith).
31.2		Rule 13a-14(a)/15d-14(a) Certification of Thomas M. O’Flynn (filed herewith).
32.1		Section 1350 Certification of Andrés Gluski (filed herewith).
32.2		Section 1350 Certification of Thomas M. O’Flynn (filed herewith).
101.INS		XBRL Instance Document (filed herewith).
101.SCH		XBRL Taxonomy Extension Schema Document (filed herewith).
101.CAL		XBRL Taxonomy Extension Calculation Linkbase Document (filed herewith).
101.DEF		XBRL Taxonomy Extension Definition Linkbase Document (filed herewith).
101.LAB		XBRL Taxonomy Extension Label Linkbase Document (filed herewith).
101.PRE		XBRL Taxonomy Extension Presentation Linkbase Document (filed herewith).

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.



		THE AES CORPORATION (Registrant)

Date:	May 6, 2016	By:	/s/ THOMAS M. O’FLYNN
			Name:	Thomas M. O’Flynn
			Title:	Executive Vice President and Chief Financial Officer (Principal Financial Officer)

		By:	/s/ FABIAN E. SOUZA
			Name:	Fabian E. Souza
			Title:	Vice President and Controller (Principal Accounting Officer)