UNITED STATES SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549

FORM 20-F

o	REGISTRATION STATEMENT PURSUANT TO SECTION 12(b) OR (g)
	OF THE SECURITIES EXCHANGE ACT OF 1934
	or
x	ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d)
	OF THE SECURITIES EXCHANGE ACT OF 1934
	For the fiscal year ended December 31, 2012
	or
o	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d)
	OF THE SECURITIES EXCHANGE ACT OF 1934
	or
o	SHELL COMPANY REPORT PURSUANT TO SECTION 13 OR 15(d)
	OF THE SECURITIES EXCHANGE ACT OF 1934
	Date of event requiring this shell company report: N/A
	Commission file number 1-15224

COMPANHIA ENERGÉTICA DE MINAS GERAIS – CEMIG

(Exact name of Registrant as specified in its charter)

ENERGY CO OF MINAS GERAIS

(Translation of Registrant’s name into English)

BRAZIL

(Jurisdiction of incorporation or organization)

Avenida Barbacena, 1200, Belo Horizonte, M.G., 30190-131

(Address of principal executive offices)

Securities registered or to be registered pursuant to Section 12(b) of the Act:

Title of each class:	Name of exchange on which registered:
Preferred Shares, R$5.00 par value	New York Stock Exchange*
American Depositary Shares, each	New York Stock Exchange
representing 1 Preferred Share, without par value
Common Shares, R$5.00 par value	New York Stock Exchange*
American Depositary Shares, each	New York Stock Exchange
representing 1 Common Share,
without par value

Securities registered or to be registered pursuant to Section 12(g) of the Act:

None

Securities for which there is a reporting obligation pursuant to Section 15(d) of the Act:

None

Indicate the number of outstanding shares of each of the issuer’s classes of capital or common stock as of the close of the period covered by the annual report:

372,837,085 Common Shares

480,181,143 Preferred Shares

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes x No o

If this report is an annual or transition report, indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934.  Yes o No x

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 o

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 o No o

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, or a non-accelerated filer.  See definition of “accelerated filer and large accelerated filer” in Rule 12b-2 of the Exchange Act. (Check one):  Large accelerated filer x Accelerated Filer o Non accelerated filer o

Indicate by check mark which basis of accounting the registrant has used to prepare the financial statements included in this filing: U.S. GAAP o IFRS x Other o

If “Other” has been checked in response to the previous question, indicate by check mark which financial statement item the registrant has elected to follow: Item 17 o Item 18 o

If this is an annual report, indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act) Yes o No x

* Not for trading but only in connection with the registration of American Depositary Shares, pursuant to the requirements of the Securities and Exchange Commission.

Table of Contents

PART I		4
Item 1.	Identity of Directors, Senior Management and Advisers	4
Item 2.	Offer Statistics and Expected Timetable	4
Item 3.	Key Information	4
Item 4.	Information on the Company	19
Item 4A.	Unresolved Staff Comments	70
Item 5.	Operating and Financial Review and Prospects	70
Item 6.	Directors, Senior Managers and Employees	95
Item 7.	Major Shareholders and Related Party Transactions	106
Item 8.	Financial Information	107
Item 9.	The Offer and Listing	115
Item 10.	Additional Information	119
Item 11.	Quantitative and Qualitative Disclosures about Market Risk	133
Item 12.	Description of Securities Other than Equity Securities	135
PART II		136
Item 13.	Defaults, Dividend Arrearages and Delinquencies	136
Item 14.	Material Modifications to the Rights of Security Holders and Use of Proceeds	136
Item 15.	Controls and Procedures	137
Item 16A.	Audit Committee Financial Expert	138
Item 16B.	Code of Ethics	138
Item 16C.	Principal Accountant Fees and Services	138
Item 16D.	Exemptions from the Listing Standards for Audit Committees	139
Item 16E.	Purchases of Equity Securities by the Issuer and Affiliated Purchasers	139
Item 16F.	Change in Registrant’s Certifying Accountant	139
Item 16G.	Corporate Governance	139
PART III		141
Item 17.	Financial Statements	141
Item 18.	Financial Statements	141
Item 19.	Exhibits	142

PRESENTATION OF FINANCIAL INFORMATION

Companhia Energética de Minas Gerais–CEMIG is a sociedade por ações, de economia mista (a state-controlled mixed capital company) organized under the laws of the Federative Republic of Brazil, or Brazil. References in this annual report to “CEMIG,” “we,” “us,” “our” and the “Company” are to Companhia Energética de Minas Gerais–CEMIG and its consolidated subsidiaries, except when the reference is specifically to Companhia Energética de Minas Gerais–CEMIG (parent company only) or the context otherwise requires. References to the “real,” “reais” or “R$” are to Brazilian reais (plural) and the Brazilian real (singular), the official currency of Brazil, and references to “U.S. dollars,” “dollars” or “US$” are to United States dollars.

We maintain our books and records in reais. We prepare our financial statements in accordance with accounting practices adopted in Brazil, and with International Financial Reporting Standards or “IFRS”, as issued by the International Accounting Standards Board (IASB). For purposes of this annual report we prepared the consolidated statements of financial position as of December 31, 2012 and 2011 and the related consolidated statements of income and comprehensive income, cash flows and changes in shareholders’ equity for the years ended December 31, 2012, 2011 and 2010, in reais in accordance with International Financial Reporting Standards or IFRS, as issued by the IASB. Deloitte Touche Tohmatsu Auditores Independentes has audited our consolidated financial statements as of and for the year ended December 31, 2012 and KPMG Auditores Independentes has audited our consolidated financial statements as of and for the years ended December 31, 2011 and 2010, as stated in their respective reports appearing elsewhere herein.

This annual report contains translations of certain real amounts into U.S. dollars at specified rates solely for the convenience of the reader. Unless otherwise indicated, such U.S. dollar amounts have been translated from reais at an exchange rate of R$2.0476 to US$1.00, as certified for customs purposes by the U.S. Federal Reserve Board as of December 31, 2012. See “Item 3. Key Information–Exchange Rates” for additional information regarding exchange rates. We cannot guarantee that U.S. dollars can be converted into reais, or that reais can be converted into U.S. dollars, at the above rate or at any other rate.

MARKET POSITION AND OTHER INFORMATION

The information contained in this annual report regarding our market position is, unless otherwise indicated, presented for the year ended December 31, 2012 and is based on, or derived from, reports issued by the Agência Nacional de Energia Elétrica (the Brazilian National Electric Energy Agency), or Aneel, and by the Câmara de Comercialização de Energia Elétrica (the Brazilian Electric Power Trading Chamber), or CCEE.

Certain terms are defined the first time they are used in this annual report. As used herein, all references to “GW” and “GWh” are to gigawatts and gigawatt hours, respectively, references to “MW” and “MWh” are to megawatts and megawatt-hours, respectively, and references to “kW” and “kWh” are to kilowatts and kilowatt-hours, respectively.

References in this annual report to the “common shares” and “preferred shares” are to our common shares and preferred shares, respectively. References to “Preferred American Depositary Shares” or “Preferred ADSs” are to American Depositary Shares, each representing one preferred share. References to “Common American Depositary Shares” or “Common ADSs” are to American Depositary Shares, each representing one common share. Our Preferred ADSs and Common ADSs are referred to collectively as “ADSs,” and Preferred American Depositary Receipts, or Preferred ADRs and Common American Depositary Receipts, or Common ADRs, are referred to collectively as “ADRs.”

On April 29, 2009, a 25.00% stock dividend was paid on the preferred and common shares. On May 13, 2009, a corresponding adjustment was made to the ADSs through the issuance of additional ADSs. On April 29, 2010, a 10.00% stock dividend was paid on the preferred and common shares. On May 10, 2010, a corresponding adjustment was made to the ADSs through the issuance of additional ADSs. On April 30, 2012, a 25.00% stock dividend was paid on the preferred shares and common shares. On May 11, 2012, a corresponding adjustment was made to the ADSs through the issuance of additional ADSs. On May 7, 2013, subject to the approval of the shareholders at the General Meeting to be held on April 30, 2013, a 12.85% stock dividend will be paid on the preferred and common shares. On May 14, 2013, subject to the approval of the shareholders at the General Meeting to be held on April 30, 2013, a corresponding adjustment will be made to the ADSs through the issuance of additional ADSs. The Preferred ADSs are evidenced by Preferred ADRs, issued pursuant to a Second Amended and Restated Deposit Agreement, dated as of August 10, 2001, as amended on June 11, 2007, by and among us, Citibank, N.A., as depositary, and the holders and beneficial owners of Preferred ADSs evidenced by Preferred ADRs issued thereunder (the “Second Amended and Restated Deposit Agreement”). The Common ADSs are evidenced by Common ADRs, issued pursuant to a Deposit Agreement, dated as of June 12, 2007, by and among us, Citibank, N.A., as depositary, and the holders and beneficial owners of Common ADSs evidenced by Common ADRs issued thereunder (the “Common ADS Deposit Agreement” and, together with the Second Amended and Restated Deposit Agreement, and on the “Deposit Agreements”).

1

FORWARD-LOOKING INFORMATION

This annual report includes forward-looking statements, principally in “Item 3. Key Information,” “Item 5, Operating and Financial Review and Prospects” and “Item 11. Quantitative and Qualitative Disclosures about Market Risk.” We have based these forward-looking statements largely on our current expectations and projections about future events and financial trends affecting our business. These forward-looking statements are subject to risks, uncertainties and assumptions relating to, among other things:

·general economic, political and business conditions, principally in Latin America, Brazil, the State of Minas Gerais, in Brazil, or Minas Gerais, the State of Rio de Janeiro, in Brazil, or Rio de Janeiro, as well as other states in Brazil;

·inflation and changes in currency exchange rates;

·enforcement of legal regulation in Brazil’s electricity sector;

·changes in volumes and patterns of consumer electricity usage;

·competitive conditions in Brazil’s electricity generation, transmission and distribution markets;

·our expectations and estimates concerning future financial performance, financing plans and the effects of competition;

·our level of debt and the maturity profile of our debt;

·the likelihood that we will receive payment in connection with accounts receivable;

·trends in the electricity generation, transmission and distribution industry in Brazil, and in particular in Minas Gerais and Rio de Janeiro;

·changes in rainfall and the water levels in the reservoirs used to run our hydroelectric power generation facilities;

·our capital expenditure plans;

·our ability to serve our consumers on a satisfactory basis;

·our ability to renew our concessions, approvals and licenses on terms as favorable as those currently in effect or at all;

·existing and future governmental regulation as to electricity rates, electricity usage, competition in our concession area and other matters;

·our ability to integrate the operations of companies we have acquired and that we may acquire;

·existing and future policies of the Federal Government of Brazil, which we refer to as the Federal Government;

·existing and future policies of the government of Minas Gerais, which we refer to as the State Government, including policies affecting its investment in us and the plans of the State Government for future expansion of electricity generation, transmission and distribution in Minas Gerais; and

·other risk factors as set forth under “Item 3. Key Information—Risk Factors.”

The forward-looking statements referred to above also include information with respect to our capacity expansion projects that are under way and those that we are currently evaluating. In addition to the above risks and uncertainties, our potential expansion projects involve engineering, construction, regulatory and other significant risks, which may:

·delay or prevent successful completion of one or more projects;

·increase the costs of projects; and

2

·result in the failure of facilities to operate or generate income in accordance with our expectations.

The words “believe,” “may,” “will,” “estimate,” “continue,” “anticipate,” “intend,” “expect” and similar words are intended to identify forward-looking statements. We undertake no obligation to update publicly or revise any forward-looking statements because of new information, future events or otherwise. In light of these risks and uncertainties, the forward-looking information, events and circumstances discussed in this annual report might not occur. Our actual results and performance could differ substantially from those anticipated in our forward-looking statements.

3

PART I

Item 1.Identity of Directors, Senior Management and Advisers

Not applicable.

Item 2.Offer Statistics and Expected Timetable

Not applicable.

Item 3.Key Information

Selected Consolidated Financial Data

The following tables present our selected consolidated financial and operating information in IFRS as of the dates and for each of the periods indicated. You should read the following information together with our consolidated financial statements, including the notes thereto, included in this annual report and the information set forth in “Item 5. Operating and Financial Review and Prospects” and “Presentation of Financial Information.”

The selected consolidated financial data as of December 31, 2012, 2011 and 2010 and for each of the years ended December 31, 2012, 2011 and 2010, in IFRS, has been derived from our audited consolidated financial statements and the notes thereto included elsewhere in this annual report. U.S. dollar amounts in the table below are presented for your convenience. Unless otherwise indicated, these U.S. dollar amounts have been translated from reais at R$2.0476  per US$1.00, the exchange rate as of December 31, 2012. The real has historically experienced high volatility. We cannot guarantee that U.S. dollars can be converted into reais, or that reais can be converted into U.S. dollars, at the above rate or at any other rate. On April 19, 2013, the exchange rate for reais was R$2,0075 per US$1.00. See “—Exchange Rates.”

Certain balances in the prior year financial statements, although not material in scale, were reclassified for the purposes of comparison with the financial statements for the year ended December 31, 2012. The prior period errors were neither material nor intentional. Although the adjustments were not material in scale, individually or in aggregate, the Company decided to adjust the comparative balances of 2011 and 2010 for the presentation of the financial statements for 2012, with the objective of maintaining the optimum comparison of the balances. Neither net profits nor net assets were adjusted as a result of the reclassifications. Refer to note 2.5 of our consolidated financial statements for further details.

Selected Consolidated Financial Data in IFRS

Selected Consolidated Financial Data in IFRS	As and for the year ended December 31,
	2012	2012	2011	2010	2009
	(in millions of US$)(1)	(in millions of R$ except per share/ADS data or otherwise indicated)
Income Statement Data:
Net operating revenues:
Electricity sales to final consumers	8,142	16,671	14,955	13,219	13,233
Revenue from wholesale supply to other concession holders and PROINFA	948	1,942	1,613	1,469	1,638
Revenue from use of the electricity distribution grid (TUSD)	1,082	2,216	1,978	1,658	1,332
Revenue from use of the concession transmission system	818	1,675	1,407	1,141	879
Transmission indemnity revenue	94	192	-	-	-
Construction revenues	797	1,631	1,541	1,341	1,291
Transactions in electricity on the CCEE	209	427	269	133	137
Other operating revenues	647	1,324	983	924	652
Taxes on revenue and regulatory charges	(3,720)	(7,618)	(6,997)	(6,095)	(5,737)
Total net operating revenues	9,017	18,460	15,749	13,790	13,425

4

Selected Consolidated Financial Data in IFRS	As and for the year ended December 31,
	2012	2012	2011	2010	2009
	(in millions of US$)(1)	(in millions of R$ except per share/ADS data or otherwise indicated)
Operating costs and expenses:
Electricity purchased for resale	(2,906)	(5,951)	(4,278)	(3,722)	(3,199)
Charges for the use of transmission facilities of the basic grid	(494)	(1,011)	(830)	(729)	(853)
Depreciation and amortization	(489)	(1,001)	(983)	(927)	(904)
Personnel	(665)	(1,361)	(1,249)	(1,212)	(1,318)
Gas purchased for resale	(242)	(495)	(329)	(225)	(167)
Royalties for usage of water resources	(91)	(186)	(154)	(140)	(154)
Outsourced services	(550)	(1,127)	(1,031)	(923)	(819)
Post-employment obligations	(65)	(134)	(124)	(107)	(150)
Materials	(40)	(82)	(98)	(134)	(114)
Provisions for operating losses	(382)	(782)	(257)	(138)	(124)
Employee’ and managers’ profit sharing	(119)	(244)	(221)	(325)	(239)
Construction costs	(796)	(1,630)	(1,529)	(1,328)	(1,410)
Other operating expenses, net	(310)	(634)	(362)	(321)	(316)
Total operating costs and expenses	(7,149)	(14.638)	(11,445)	(10,231)	(9,767)
Equity in Subsidiaries	(1)	(3)	(1)	-	-
Gain on dilution of interest in jointly controlled subsidiaries	129	264	-	-	-
Operational profit before Financial revenue (expenses) and Taxes	1,996	4,083	4,303	3,559	3.658
Financial revenues (expenses), net	611	1,252	(970)	(753)	(326)
Profit before taxes	2,607	5,335	3,333	2,806	3,332
Income taxes expense	(519)	(1,063)	(918)	(548)	(1,126)
Profit for the year	2,088	4,272	2,415	2,258	2,206
Non-controlling interests					(73)
Other comprehensive income (loss)	1	3	6
Comprehensive income	2,089	4,275	2,421	2,258	2,133
Basic earnings (loss): (2)
Per common share	2.45	5.01	2.83	2.65	2.59
Per preferred share	2.45	5.01	2.83	2.65	2.59
Per ADS	2.45	5.01	2.83	2.65	2.59
Diluted earnings (loss): (2)
Per common share	2.45	5.01	2.83	2.65	2.59
Per preferred share	2.45	5.01	2.83	2.65	2.59
Per ADS	2.45	5.01	2.83	2.65	2.59

5

	As and for the year ended December 31,
	2012	2012	2011	2010	2009
	(in millions of US$)(1)	(in millions of R$ except per share/ADS data or otherwise indicated)
Balance Sheet Data:
Assets:
Current assets	5,856	11,990	8,532	8,086	8,617
Property, plant and equipment, net	4,303	8,811	8,662	8,229	8,303
Intangible assets	2,185	4,473	5,404	4,948	3,705
Financial assets of concessions	5,453	11,166	9,086	7,672	5,508
Account receivable from the Minas Gerais State Government	-	-	1,830	1,837	1,824
Other assets	2,116	4,333	3,495	2,702	2,337
Total assets	19,913	40,773	37,009	33,474	30,294
Liabilities:
Current portion of long-term financing	3,470	7,106	7,821	2,203	6,659
Other current liabilities	3,517	7,201	4,348	4,200	3,620
Total current liabilities	6,987	14,307	12,169	6,403	10,279
Non-current financing	4,427	9,064	7,958	11,024	4,634
Employee post-retirement benefits non-current.	1,089	2,229	2,187	2,062	1,915
Other non-current liabilities	1,528	3,129	2,950	2,509	2,301
Total non-current liabilities	7,010	14,422	13,095	15,595	8,850
Share capital	2,083	4,265	3,412	3,412	3,102
Capital reserves	1,931	3,954	3,954	3,954	3,969
Profit reserves	1,395	2,856	3,293	2,874	3,177
Accumulated other comprehensive income	471	965	1,081	1,211	1,343
Other shareholders´equity	2	4	5	25	(426)
Total shareholders´equity	5,882	12,044	11,745	11,476	11,165
Total liabilities and shareholders´equity	19,913	40,773	37,009	33,474	30,294

Other Data:

Outstanding shares basic:(2)	2012	2011	2010	2009
Common	372,837,085	372,837,085	372,837,085	372,837,085
Preferred	480,181,143	480,181,143	480,181,143	480,181,143
Dividends per share (2)
Common	R$2.50	R$1.52	R$1.40	R$1.09
Preferred	R$2.50	R$1.52	R$1.40	R$1.09
Dividends per ADS (2)	R$2.50	R$1.52	R$1.40	R$1.09
Dividends per share (3)(2)
Common	US$1.22	US$0.74	US$0.69	US$0.53
Preferred	US$1.22	US$0.74	US$0.69	US$0.53
Dividends per ADS (3)(2)	US$1.22	US$0.74	US$0.69	US$0.53
Outstanding shares—diluted: (2)
Common	372,837,085	372,837,085	372,837,085	372,837,085
Preferred	480,181,143	480,181,143	480,181,143	480,181,143
Dividends per share diluted (2)
Common	R$2.50	R$1.52	R$1.40	R$1.09
Preferred	R$2.50	R$1.52	R$1.40	R$1.09
Dividends per ADS diluted (2)	R$2.50	R$1.52	R$1.40	R$1.09
Dividends per share diluted (3)(2)
Common	US$1.22	US$0.74	US$0.69	US$0.53
Preferred	US$1.22	US$0.74	US$0.69	US$0.53
Dividends per ADS diluted (3)(2)	US$1.22	US$0.74	US$0.69	US$0.53

(1)           Converted at the exchange rate of US$1.00 to R$2.0476, the exchange rate as of December 31, 2012. See “—Exchange Rates.”

(2)           Per share numbers have been adjusted to reflect the stock dividends on our shares in April 2012, and per ADS numbers have been adjusted to reflect the corresponding adjustments to our ADS.

(3)           This information is presented in U.S. dollars at the exchange rate in effect as of the end of each year.

6

Exchange Rates

On March 4, 2005, the National Monetary Council (Conselho Monetário Nacional), or CMN, consolidated the commercial rate exchange market and the floating rate market into a single exchange market. Such regulation allows, subject to certain procedures and specific regulatory provisions, the purchase and sale of foreign currency and the international transfer of reais by a foreign person or company, without limitation as to amount. Additionally, all foreign exchange transactions must be carried out by financial institutions authorized by the Brazilian Central Bank (Banco Central do Brasil), or the Central Bank, to operate in this market.

Brazilian law provides that whenever there (i) is a significant imbalance in Brazil’s balance of payments or (ii) are major reasons to foresee a significant imbalance in Brazil’s balance of payments, temporary restrictions may be imposed on remittances of foreign capital abroad.  In the past, the Central Bank has intervened occasionally to control unstable movements in foreign exchange rates. We cannot predict whether the Central Bank or the Federal Government will continue to let the real float freely or will intervene in the exchange rate market. The real may depreciate or appreciate against the U.S. dollar and other currencies substantially in the future. Exchange rate fluctuations may affect the U.S. dollar amounts received by the holders of Preferred ADSs or Common ADSs. We will make any distributions with respect to our preferred shares or common shares in reais and the depositary will convert these distributions into U.S. dollars for payment to the holders of Preferred ADSs and Common ADSs. We cannot asure you that such measures will not be taken by the Brazilian Government in the future, which could prevent us from making payments to the holders of our ADSs. Exchange rate fluctuations may also affect the U.S. dollar equivalent of the real price of the preferred shares or common shares on the Brazilian stock exchange where they are traded. Exchange rate fluctuations may also affect our results of operations.  For more information see “Risk Factors — Risks Relating to Brazil — Exchange rate instability may adversely affect our business, results of operations and financial condition and the market price of our shares, the Preferred ADSs and the Common ADSs.”

The table below sets forth, for the periods indicated, the low, high, average and period-end exchange rates for reais, expressed in reais per US$1.00.

	Reais per US$1.00
Month	Low	High	Average	Period-end
October 2012	2.0210	2.0436	2.0297	2.0298
November 2012	2.0304	2.1118	2.0662	2.1118
December 2012	2.0445	2.1141	2.0775	2.0476
January 2013	1.9860	2.0478	2.0281	1.9875
February 2013	1.9564	1.9913	1.9729	1.9767
March 2013	1,9480	2,0210	1,9842	2,0210
April 2013 (1)	1,9690	2,0235	1,9973	2,0075

(1)As of April 19, 2013.

	Reais per US$1.00
Year Ended December 31,	Low	High	Average	Period-end
2008	1.5580	2.6190	1.8322	2.3130
2009	1.6995	2.4420	1.9976	1.7425
2010	1.6574	1.8885	1.7600	1.6631
2011	1.5375	1.8865	1.6723	1.8627
2012	1.6997	2.1141	1.9535	2.0476

Source: U.S. Federal Reserve Board

7

Risk Factors

You should consider the following risks as well as the other information in this annual report in evaluating an investment in our company.

Risks Relating to CEMIG

Public authorities may intervene in our concessions to ensure the appropriate provision of services, which could adversely affect our business, results of operations and financial condition.

Public authorities may intervene in concessions to ensure the appropriate provision of services, and/or faithful compliance with provisions of contracts, regulations and/or laws, and may also interfere in transactions or regulate revenues arising from operations of our facilities. Intervention from public authorities in our concessions, interference in transactions or regulation of revenue could adversely affect our business, results of operations and financial condition.

We cannot be certain of the renewal of our concessions.

We carry out a majority of our power generation, transmission and distribution activities pursuant to concession agreements entered into with the Federal Government. The Brazilian Constitution requires that all concessions relating to public services be awarded through a bidding process. In 1995, in an effort to implement these constitutional provisions, the Federal Government adopted certain laws and regulations, known collectively as the Concessions Law, governing bidding procedures in the power industry. In accordance with the Law No. 8,987 of February 13, 1995, or the Concessions Law, as modified by Federal Law No. 10,848 of March 15, 2004, or the New Industry Model Law, upon application by the concessionaire, existing concessions may be renewed by the Federal Government for additional periods of up to 20 years without being subject to the bidding process, provided that the concessionaire has met minimum performance standards and that the proposal is acceptable to the Federal Government.

On September 11, 2012 the Brazilian government issued Provisional Measure 579, or PM 579, later converted into Law No. 12,783, which governs the extension of the concessions granted before Law No. 9074 of July 9, 1995.  Under PM 579, these concessions can be extended only once, for up to 30 years, at the option of the concession-granting power. On December 4, 2012, the Company signed the third amendment to Transmission Concession Contract 006/1997, which extended concession for 30 years under the terms of PM 579 from January 1, 2013. However, the Company opted not to request extension of the generation concessions that expire within the period 2013 to 2017. For the plants that would have had a first extension before PM 579, which include the Jaguara, São Simão and Miranda plants, we believe the Generation Concession Contract 007/1997 allows for the extension of the concession of those plants for an additional 20 years, subject to no additional conditions. For the other generation companies the have concessions that expire over the period from 2015 to 2017, which includes Três Marias, Salto Grande, Itutinga, Camargos, Piau, Gafanhoto, Peti, Tronqueiras, Joasal, Martins, Cajuru, Paciência, Marmelos, Sumidouro, Anil, Poquim, Dona Rita and Volta Grande, we have opted, under the terms of PM 579, not to apply for an extension of their concessions.

In light of the degree of discretion granted to the Federal Government, in relation to new concession contracts, renewal of existing concessions, and in accordance with the provisions established by PM 579 for renewal of distribution, generation and transmission concession contracts, we cannot guarantee that new concessions will be obtained or that our present concessions will be renewed on terms as favorable as those currently in effect. See “Item 4. Information on the Company—Competition—Concessions” and “Item 4. The Brazilian Power Industry—Concessions.” Non-renewal of any of our concessions could adversely affect our business, results of operations and financial condition.

We might be unable to complete our proposed capital expenditure program.

Our by-laws state that we may use up to 40.0% of our annual EBITDA (earnings before interest, income taxes, depreciation and amortization), each fiscal year, on capital investments and acquisitions. Our ability to carry out our capital expenditure program is dependent upon a number of factors, including our ability to charge adequate rates for our services, our access to domestic and international capital markets and a variety of operating and other factors. In addition, our plans to expand our distribution capacity are subject to the competitive bidding process governed by the Concessions Law. We cannot give any assurance that we will have the financial resources to complete this program, which could affect our business, results of operations and financial condition.

Aneel has discretion to establish the rates Cemig Distribution charges consumers. These rates are determined by Aneel and designed to preserve the economic and financial equilibrium of concession contracts entered into with Aneel (acting on behalf of the Federal Government).

Concession agreements and Brazilian law establish a price cap mechanism that permits three types of rate adjustments: (1) the annual readjustment; (2) the periodic revision; and (3) the extraordinary revision. The annual readjustment is designed to

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compensate us for changes in our costs that are beyond our control, such as the cost of electricity to supply consumers, which are established by the government, and charges for transmitting and distributing electricity through  transmission and distribution facilities of other companies. Every five years there is a periodic tariff revision aimed at compensating us for the same variations in our costs considered for the annual readjustment, remunerating us for the assets we have built during the five year period, and setting a factor based on our scale gains, which will be considered in our annual rate adjustments. If there is an unforeseen event that significantly alters the economicand financial equilibrium of our concession, there may be an extraordinary revision of our rates by Aneel.

Under all three forms of readjustments, in spite of there being pre-established rules and procedures that must be followed by both Aneel and us, Aneel may act as it deems appropriate and opportune in any given situation for the benefit of consumers’ rights. Thus, although our concession agreements provide that we must remain in economic and financial balance, we cannot assure you that Aneel will establish rates that will adequately compensate us in relation to the investments made or that will fully cover the operational costs of the concession holders.

Disruptions in the operation or deterioration in the quality of our services may have an adverse effect on our business, financial condition and results of operations.

The operation of complex electricity transmission networks and systems involves various risks, such as operational difficulties and unexpected interruptions, caused by events outside of our control. These events include accidents, breakdown or failure of equipment or processes, performance below expected levels of availability and efficiency of the transmission assets and disasters such as explosions, fires, natural phenomena, landslides, sabotage or other similar events. Furthermore, actions by government agencies responsible for the electricity network, the environment, operations and other issues that affect electricity transmission could adversely affect the functioning and profitability of the operations of our transmission lines.

Our insurance coverage may not be sufficient to fully cover costs and/or losses we may incur as a result of damage to our assets and/or service interruptions, which could result in an adverse effect on our business, financial condition and results of operations. For more information on our insurance coverage risk, see “—The insurance contracted by us may be insufficient to compensate for damages.”

The revenues we generate from establishing, operating and maintaining our facilities depend on the availability of our services. If our services become unavailable, we may be subject to reductions in the Permitted Annual Revenue (Receita Anual Permitida, or “RAP”) associated with our concession agreements, and we may face certain penalties, depending on the level of duration of the service unavailability. Therefore, interruptions in our transmission lines and substations may cause a material adverse effect on our business, financial condition and results of operations.

We may incur losses in connection with pending litigation.

We are currently defending several legal and administrative proceedings relating to civil, administrative, environmental, tax, labor and other claims. These claims involve a wide range of issues and seek indemnities and reparation in money and by specific performance. Several individual disputes account for a significant part of the total amount of claims against us. Our consolidated financial statements include contingency provisions in the total amount of R$468 million as of December 31, 2012 for actions in which the existence of a present obligation on the date of the financial statements was considered to be more likely than not. Unfavourable decisions in our legal proceedings may reduce our liquidity and adversely affect our business, financial condition or results of operations. In the event our contingency provisions are insufficient, payments for actions in excess of the amounts provisioned could adversely affect our results of operations and financial condition.

The rules for the sale of electric energy and market conditions could affect our energy selling prices.

Under applicable law, our generation companies are not allowed to sell energy directly to our distribution companies. As a result, our generation companies have to sell electricity in a regulated market through public auctions conducted by Aneel (the “Regulated Market,” the “Regulated Contracting Environment - ACR,” or the “Pool”) or in the Free Market (the “ACL”). Legislation allows distributors that contract with our generation companies under the Regulated Market to reduce the quantity of energy contracted for under existing energy contracts by up to 4% per year of the original contract amount for the entire contract period, exposing our generation companies to the risk of failing to sell their remaining energy at adequate prices.

We perform trading activities through power purchase and sale agreements, mainly in the ACL, through our generation and trading subsidiaries. Contracts in the ACL may be entered into with other generating agents, energy traders, or mainly, with “Free Consumers”. Free Consumers are consumers with demand equal to or greater than 3 MW, who are allowed to choose their electricity supplier. Some contracts with this type of consumer give them the flexibility to purchase more or less energy (by 5% on average) from us than was originally contracted for by such consumers, which may adversely impact our business, results of operations and financial

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condition. Other contracts do not allow for this kind of flexibility in the purchase of energy, however, the increase in market competition in the Free Market can influence the occurrence of this type of arrangement in purchase contracts in this market.

In addition to Free Consumers, there is a category of customers referred as “Special Consumers”,  which are consumers with contracted demand between 500kW and 3MW. Special Consumers are eligible to buy energy in the Free Market so long as they buy electricity from alternative sources, such as Small Hydroelectric Plants, biomass plants or wind farms. We have conducted these types of transactions with Special Consumers through some of our own energy resources located within certain of our subsidiaries, but from 2009 on, we have increased these alternative-energy transactions, and have developed a portfolio of purchase contracts for this type of energy. The terms of these agreements for the sale of energy to Special Consumers have certain flexibilities with regards to consumption level requirements designed to meet the demands of Special Customers, which are linked to the customer’s energy consumption level history. Large variations in the market price of energy may generate short-term positions that could adversely affect our results of operations and financial condition.

The lack of liquidity in the trading market or volatility in future prices due to market conditions and/or market perceptions may negatively affect our results of operations. Also, if we are unable to sell all the power capacity under our purchase contracts in the regulated auctions or in the free market, the unsold capacity will be settled in the CCEE at settlement prices (Preços de Liquidação de Diferenças), or PLD, which tend to be very volatile. If this occurs in periods of low settlement prices, our revenues and results of operations could be adversely affected.

The introduction of Law No. 12,783 brought certain changes to the organization of the Brazilian Energy Market and the impacts of this new regulation cannot yet be assessed, however its implementation may have an adverse effect on our business and results of operations.

Requirements and restrictions by the environmental agencies could cause additional costs for us.

Our operations related to generation, distribution and transmission of electricity, and distribution of natural gas, are subject to various federal, state and municipal laws and regulations, and also to numerous requirements relating to the protection of health and the environment. Delays by the environmental authorities, or refusal of license requests by them, and/or any inability on our part to meet the requirements established by the environmental authorities during the environmental licensing process may result in additional costs, or even prohibit or restrict, depending on each individual case, the construction or maintenance of these projects.

Non-compliance with environmental laws and regulations, such as building and operation of a potentially polluting facility without a valid environmental license or authorization, could, in addition to the obligation to redress any damages that may be caused, result in criminal, civil and/or administrative sanctions being applied to us. Under Brazilian legislation, criminal penalties such as restriction of rights, and even imprisonment, may be applied to individuals (including managers of legal entities), and penalties such as fines, restriction of rights or community service may be applied to legal entities. With respect to administrative sanctions, depending on the circumstances, the environmental authorities may: impose warnings or fines, ranging from R$50 thousand to R$50 million; require partial or total suspension of activities; suspend or restrict tax benefits; cancel or suspend lines of credit from governmental financial institutions; or prohibit us from contracting with governmental agencies, companies or authorities. Any of these events could adversely affect our business, results of operation and financial condition.

We are also subject to Brazilian legislation, which requires payment of compensation in the event that our activities have polluting effects.  Under the federal legislation, up to 0.5% of the total amount invested in the implementation of a project that causes significant environmental impact must be applied toward compensation measures, in an amount to be determined on a case by case basis by environmental authorities according to the extent of the environmental impact of the project. Certain provisions of the state legislation provide that compensation measures should be adopted retroactively for projects concluded before the relevant legislation was enacted. The retroactive nature of these provisions is being contested by some companies, and the matter is also being discussed between The Minas Gerais State Environment and Sustainable Development Office (Secretaria de Estado de Meio-Ambiente e Desenvolvimento Sustentável, or Semad), the Office of the Attorney General of the State (Procuradoria Geral do Estado, or PGE), and the Minas Gerais Industries Association (Federação das Indústrias de Minas Gerais, or Fiemg), and it is not yet clear whether such provisions will be applied in practice. At this moment, it is not possible to evaluated the effects of this legislation on us, but such legislation may result in additional costs for us, which could adversely affect our business, results of operations and financial condition. See “Item 4. Information on the Company — Environmental Issues — Compensatory Measures”.

In addition, the laws of the State of Minas Gerais require the constitution of a Legal Forest Reserve, corresponding to 20% of the total area of the rural property, used in our operations. Due to the Opinion of the Minas Gerais State Economic Development Office (Secretaria Estadual de Desenvolvimento Econômico, or SEDE), that the Legal Forest Reserve does not apply to hydroelectric operations and the impact of the New Brazilian Forest Code on legislation in the State of Minas Gerais, this issue has not yet been decided. There also has not been any final decision on the application of the Legal Forest Reserve requirement to projects already in operation and to future projects. At this moment, it is not possible to evaluated the effects of such legislation on us, but it could

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adversely affect our business, results of operations and financial condition.  See “Item 4. Information on the Company — Environmental Issues — Legal Forest Reserves”.

Finally, the adoption or implementation of new safety, health and environmental laws, new interpretations of existing laws, increased rigidity in the application of the environmental laws, or other developments in the future might require us to make additional capital expenditure or incur operating expenses in order to maintain our current operations; or to curtail our production activities or take other actions that could have an adverse effect on our business, results of operation or financial condition.

We are controlled by the State Government which may have specific interests in our business that are different from yours.

As our controlling shareholder, the government of the State of Minas Gerais exercises substantial influence on the strategic orientation of our business. The government of the State of Minas Gerais currently holds approximately 51% of our common shares and, consequently, has the right to the majority of votes in decisions of the General Meetings of our Shareholders, and can (i) elect the majority of the members of our Board of Directors, and (ii) decide matters requiring approval by a specific majority of our shareholders, including transactions with related parties, shareholding reorganizations and the date and payment of any dividends.

In the past, the State Government has used, and may in the future use, its status as our controlling shareholder to decide whether we should engage in certain activities and make certain investments aimed, principally, to promote its political, economic or social objectives and not necessarily to meet the objective of improving our business and/or operational results. Such actions could materially adversely affect our business, results of operation and financial condition.

Delays in the expansion of our facilities may significantly increase our costs.

We are currently engaged in the construction of additional hydroelectric and wind farm power plants, transmission lines and substations, and the evaluation of other potential expansion projects. Our ability to complete an expansion project on time, within a given budget and without adverse economic effects, is subject to a number of risks. For instance:

·we may experience problems in the construction phase of an expansion project; (e.g.: work stoppages, unforeseen geological conditions, environmental and political uncertainties, liquidity of partners and contractors.

·we may face regulatory or legal challenges that delay the initial operation date of an expansion project;

·our new facilities may not operate at the designated capacity the cost of the operation may be greater than forecast;

·we may face a delay in relation to planned deadlines on a project;

·we may not be able to obtain adequate working capital to finance our expansion projects; and

·we may encounter environmental issues and claims by the local population during power plant construction or related to the transmission lines and substation construction.

If we experience these or other problems relating to the expansion of our electricity generation or transmission capacity we may be exposed to increased costs or we may fail to achieve the revenues we expected in connection with such expansion projects.

Aneel has discretion in setting the Permitted Annual Revenue of our transmission companies, and any adjustments that result in a decrease to such Permitted Annual Revenue could have a material adverse effect on our results of operations and financial condition.

The RAP that we receive through our transmission companies is determined by Aneel taking into account the terms of the concession contracts entered into with Aneel, on behalf of the Federal Government. The concession contracts and the law provide that the revenues of transmission companies are decided by Aneel, and are calculated based on the availability of assets (lines and substations) to the Brazilian National Electric Grid (Sistema Interligado Nacional, or SIN). The concession contracts provide for two mechanisms for adjustment of revenues: (i) annual tariff adjustments; and (ii) the periodic tariff review (revisão tarifária periódica, or RTP). The annual tariff adjustment of our transmission revenues takes place annually in June and is effective in July of the same year. The annual tariff adjustments consider the permitted revenues of the projects that have come into operation and the revenue from the previous period is adjusted by the Amplified National Consumer Price Index (Índice Nacional de Preços ao Consumidor Amplo, or IPCA). The periodic tariff review used to take place every four years, but Law No. 12,783 changed the tariff review period to five years. Our first periodic tariff review took place in July 2005 and the second in July 2009. During the periodic tariff review, the investments made by the concession holder in the period and the operational costs of the concession are analyzed by Aneel, taking into account only investment that it deems to be prudent, and operational costs that it assesses as having been efficient through a benchmarking methodology developed by utilizing an efficiency model based on data comparison among several Brazilian

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transmission companies. Therefore, the tariff review mechanism is subject to some extent to the discretionary power of Aneel, since it may omit to include investments that have been made, and can recognize operational costs as being lower than those actually incurred, which may result in a material adverse effect on our business, results of operations and financial condition.

As mentioned above, we extended the concessions of certain of our transmission utilities by the terms of  Law No. 12,783, which resulted in an adjustment to the RAP of those concessions, lowering the revenue we will received from such concessions.  The Brazilian Government compensated us for a reduction in the RAP of a portion of these concessions, but the assets in operation before 2000 have not yet been compensated. According to Law No. 12,783, we will be compensated for the reduction in the RAP of the assets in operation before 2000 in 30 years, adjusted by the IPCA.

Labor-related legal claims, strikes and/or work stoppages could have an adverse impact on our business.

Substantially all of our employees are covered by Brazilian labor legislation applicable to private sector employees. We have entered into collective bargaining agreements with the labor unions representing most of these employees.

We are currently defending a number of labor-related claims brought by our employees that mostly relate to overtime and compensation for occupational hazards. We are also subject to claims related to outsourcing of services, in which employees of our contractors and subcontractors have brought actions against us for the payment of outstanding labor liabilities. See “Item 8. Financial Information—Legal Proceedings—Labor and Pension Fund Obligations.”

In the negotiations for reaching the 2010 collective agreement, part of our employees went on strike for 20 days. During the 2011 negotiations for renewal of the Collective Employment Agreement (Acordo Coletivo de Trabalho, or ACT), there were five intermittent days of stoppages by our employees. During the 2012 negotiations for the renewal of the ACT, there was one day of stoppage by 12% of our employees. In all of these events, our Operational Emergency Committee was activated and the strikes and stoppages did not affect the supply of electricity to our consumers.

We do not have insurance against losses incurred as a result of business interruptions caused by employment-related actions. In the event of a strike, we may face an immediate loss of revenue. Contractual disputes, strikes, complaints or other types of conflicts relating to our employees or to unions that represent them may cause an adverse effect on our business, results of operations or financial condition, or on our ability to maintain normal levels of service.

We are subject to rules and limits applied to levels of public sector borrowing and to restrictions on the use of certain funds we raise, which could prevent us from obtaining financing.

As a state-controlled company, we are subject to rules and limits on the level of credit applicable to the public sector issued by the CMN and by the Central Bank. These rules set certain parameters and conditions for financial institutions to be able to offer credit to public sector entities. Thus, if our operations do not fall within these parameters and conditions, we may have difficulty in obtaining financing from Brazilian financial institutions, which could create difficulties in the implementation of our investment plan. Brazilian legislation also establishes that a state-controlled company, in general, may use proceeds from external transactions with commercial banks (debt, including bonds) only to refinance financial obligations. As a result of these regulations, our capacity to incur debt is limited, and this could negatively affect the implementation of our investment plan.

We are subject to extensive and uncertain governmental legislation and regulation and any changes to such legislation and regulation could materially adversely affect our business, results of operations and financial condition.

The Brazilian Federal Government has been implementing policies that have a far-reaching impact on the Brazilian energy sector and, in particular, the electricity industry. As part of the restructuring of the industry, the New Industry Model Law, introduced a new regulatory framework for the Brazilian electricity industry.

This regulatory structure has undergone several changes over recent years, the most recent being PM 579, which governs the extension of the concessions granted by Law No. 9,074 of July 7, 1995. Under this law, these concessions can be extended only once for up to 30 years, at the option of the concession-granting power.

The constitutionality of the New Industry Model Law is currently being challenged before the Brazilian Supreme Court (Supremo Tribunal Federal, or STF). As of the date of this report, the STF had not reached a final decision, and therefore, the New Industry Model Law is in full force and effect. If the New Industry Model Law is considered to be unconstitutional by the STF, the regulatory framework introduced by that law might cease to be in effect, which would generate uncertainty as to how and when the

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Federal Government will be able to introduce changes to the electricity industry. Therefore, any decision on the constitutionality of the New Industry Model Law could have a material adverse effect on our activities, results of operations and financial condition.

Also, we cannot guarantee that new concessions will be obtained or that our present concessions will be renewed on terms that are as favorable as those currently in effect.

There are contractual restrictions on our capacity to incur debt.

We are subject to certain restrictions on our ability to incur debt due to covenants set forth in our loan agreements. In the event of our non-compliance with any such covenants in our loan agreements, the total principal, future interest and any penalties due under these agreements may become immediately due and payable. In 2010, 2011 and 2012, we were at times in non-compliance with our covenants under our loan agreements, but we were able to obtain waivers from our creditors with regard to such non-compliances. As to 2012, in particular, the figures that gave rise to the waiver from ItaúBBA were preliminary and the actual figures ended up being not compatible with the obtained waiver. As another waiver was not obtained prior to December 31, 2012, not only the loan but others with cross-default conditions had to be recognized as a current liability. The amount transferred to current liabilities as a result of non-compliance with the covenant was R$ 1,206 million. We expect to obtain the waiver from ItaúBBA in May 2013. Although we have succeeded in obtaining the waivers, no assurance can be given that we would be successful in obtaining any waivers in the future. Early maturity of our obligations could adversely affect our financial condition especially in light of cross default provisions in several of our loan and financing contracts. The existence of limitations on our indebtedness could prevent us from executing new agreements to finance our operations or to refinance our existing obligations which could adversely affect our business, results of operations and financial condition.

We operate without insurance policies against catastrophes and general third party liability.

We do not have general third party liability insurance covering accidents, other than in connection with Aeronautical events, and have not asked for bids related to this type of insurance. In addition, we have not asked for bids for, nor do we carry, insurance coverage for major catastrophes affecting our facilities, such as earthquakes and floods, nor for business interruption risk; nor for operating system failures. Accidents or catastrophic events may materially adversely affect our business, results of operations or financial condition. See “Item 10. Additional Information—Insurance.”

The insurance contracted by us may be insufficient to compensate for damages.

The Company maintains insurance only for fire , risks involving our aircrafts and helicopters, and operational risks, such as damage to equipment, as well as those types of insurance coverage that are required by law, including transport insurance for goods belonging to us.

We cannot guarantee that our insurance policies are sufficient to cover in full any liabilities that may arise in the course of our business nor that these insurance policies will continue to be available in the future. The occurrence of claims in excess of the amount insured or which are not covered by our insurance policies might generate significant and unexpected additional costs for us, which could have a material adverse effect on our business, results of operation and financial condition.

Our level of consumer default could adversely affect our business, results of operations and financial condition.

As of December 31, 2012, our total past due receivables from final consumers were approximately R$1,324 million, corresponding to 7.17% of our net revenues for 2012, and our allowance for doubtful accounts was R$723 million. Approximately 12,54% our total receivables were owed by entities in the public sector. We may be unable to recover debts from several municipalities and other defaulting consumers. If these debts are not totally or partially recovered, we will experience an adverse impact on our business, results of operations and financial condition. In addition, any consumer defaults in excess of our allowance for doubtful accounts could have an adverse effect on our business, results of operations and financial condition.

We are strictly liable for any damages resulting from inadequate rendering of electricity services.

Under Brazilian law, we are strictly liable for direct and indirect damages resulting from the inadequate rendering of electricity distribution services. In addition, when damages are caused to end consumers as a result of outages or disturbances in the generation, transmission and distribution system, whenever these outages or disturbances are not attributed to an identifiable member of the National System Operator (Operador Nacional do Sistema, or ONS) or to the ONS itself, the liability for such damages is shared among generation, distribution and transmission companies. Until a final allocation is defined, the liability for such damages will be shared in the proportion of 35.7% to distribution agents, 28.6% to transmission agents and 35.7% to generation agents. These proportions are established by the number of votes that each class of energy concessionaires receives in the general meeting of the

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ONS, and as such, they are subject to change in the future. Our business, results of operations and financial condition might be adversely affected as a result of any such damages.

Aneel may impose fines on us for failing to comply with the terms and conditions of our concession agreements, and/or the authorizations granted to us, which could result in fines, other penalties and, depending on the severity of non-compliance, expropriation of the concession agreements or revocation of the authorizations.

We conduct our generation, transmission and distribution activities pursuant to concession agreements entered into with the Federal Government through Aneel and/or pursuant to authorizations granted to the companies of our portfolio, as the case may be. Aneel may impose penalties on us if we fail to comply with any provision of the concession agreements, including compliance with the established quality standards. Depending on the severity of the non-compliance, these penalties could include:

·fines per breach of contract of up to 2.0% of the concessionaire’s revenues in the year ended immediately prior to the date of the relevant breach;

·injunctions related to the construction of new facilities and equipment;

·restrictions on the operation of existing facilities and equipment;

·temporary suspension from participating in bidding processes for new concessions for a period of up to two years;

·intervention by Aneel in the management of the concessionaire that it is in breach; and

·termination of the concession.

In addition, the Federal Government has the power to terminate any of our concessions or authorizations, prior to the end of the concession term in the case of bankruptcy or dissolution, or by means of expropriation for reasons related to the public interest.

Also, delays regarding the implementation and construction of new energy undertakings can also trigger the imposition of regulatory penalties by Aneel, which, under Aneel’s Resolution No. 63 of May 12, 2004, can vary from warnings to the early termination of these concessions or authorizations.

We cannot guarantee that Aneel will not impose penalties or terminate our concessions or authorizations in the event of a breach. Any compensation we may receive upon the termination of the concession contract and/or the authorizations may not be sufficient to compensate us for the full value of certain investments. If any of our concession agreements are terminated and we are at fault, the effective amount of compensation could be reduced through fines or other penalties. Termination of our concession contracts, or imposition of penalties might adversely affect our business, results of operations and financial condition.

Our ability to distribute dividends is subject to limitations.

Whether or not you receive dividends depends on whether our financial condition permits us to distribute dividends under Brazilian law, and whether our shareholders, on the recommendation of our Board of Directors acting in its discretion, determine that our financial condition warrants a suspension of the distribution of dividends in excess of the amount of mandatory distribution required under our by-laws, in the case of the preferred shares.

Because we are a holding company with no revenue-producing operations other than those of our operating subsidiaries, we will be able to distribute dividends to shareholders only if we receive dividends or other cash distributions from our operating subsidiaries. The dividends that our subsidiaries may distribute to us depend on our subsidiaries generating sufficient profit in any given fiscal year. Dividends can be paid out from the profit accrued in each fiscal year, or from accumulated profits from previous years, or from capital reserves. Such dividends are calculated and paid in accordance with Law No. 11,638 (which amended numerous provisions of Law No. 6,404/76), or Brazilian Corporate Law, and the provisions of the by-laws of each of our regulated subsidiaries.

We will need funds in the short term to fund our current and expected acquisitions.

We will need funds in the short term to fund our current and future acquisitions and investments. However, no assurance can be given that we will be able to raise such funds in a timely manner and in the amounts necessary or at competitive rates, or that we will otherwise have supplemental cash-on-hand available to finance our investments and our acquisitions. If we are unable to raise funds as planned, we may be unable to meet our acquisition commitments, and our investment program could suffer delays or significant changes, which could adversely affect our business, financial condition or prospects.

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Foreign shareholders may be unable to enforce judgments against our directors or officers.

All of our directors and officers named in this annual report reside in Brazil. Substantially all of our assets, as well as the assets of these persons, are located in Brazil. As a result, it may not be possible for foreign shareholders to effect service of process within the United States or other jurisdictions outside Brazil upon these persons, attach their assets, or enforce against them or us in United States courts, or the courts of other jurisdictions outside Brazil, judgments predicated upon the civil liability provisions of the securities laws of the United States or the laws of such other jurisdictions. See “Item 10. Additional Information—Difficulties of Enforcing Civil Liabilities Against Non-U.S. Persons.”

Risks Relating to Brazil

The Federal Government exercises significant influence on the Brazilian economy. Political and economic conditions can have a direct impact on our business.

The Federal Government intervenes frequently in the country’s economy and occasionally makes significant changes in monetary, fiscal and regulatory policy. Our business, results of operations or financial condition may be adversely affected by changes in government policies, and also by:

·fluctuations in the exchange rate;

·inflation;

·instability of prices;

·changes in interest rates;

·fiscal policy;

·other political, diplomatic, social and economic developments which may affect Brazil or the international markets;

·control on capital flows; and/or

·limits on foreign trade.

Measures by the Brazilian government to maintain economic stability, and also speculation on any future acts of the Brazilian government, can generate uncertainties in the Brazilian economy and uncertainties about the possible political crisis can contribute to economic stability and increased volatility in the domestic capital markets, adversely affecting our business, results of operations or financial condition. If the political and economic situations deteriorate, we may face increased costs.

The new President of Brazil took office at the beginning of 2011. The President has considerable power to determine governmental policies and actions that relate to the Brazilian economy. Uncertainties in relation to any political crises might contribute to economic instability. This could increase the volatility of the market for Brazilian securities and could have an adverse effect on the Brazilian economy and our business, results of operations and financial condition. It is not possible to predict whether the present government or any subsequent governments will have an adverse effect on the Brazilian economy, and consequently on our business.

Inflation and certain governmental measures to curb inflation may contribute significantly to economic uncertainty in Brazil and could harm our business and the market value of our shares, the Preferred ADSs and the Common ADSs.

Brazil has in the past experienced extremely high rates of inflation. Inflation, and some of the Federal Government’s measures taken in an attempt to curb inflation, have had significant negative effects on the Brazilian economy. Since the introduction of the real in 1994, Brazil’s inflation rate has been substantially lower than in previous periods. According to the IPCA, Brazilian annual inflation rates in 2010, 2011 and 2012 were 5.9%, 6.5% and 5.5%, respectively. No assurance can be given that inflation will remain at these levels.

Future measures taken by the Federal Government, including interest rate changes, intervention in the foreign exchange market or actions to adjust the value of the real might trigger increases in inflation, and consequently, have adverse economic impacts on our business, results of operations and financial condition. If Brazil experiences high inflation in the future, we might be unable to adjust the rates we charge our consumers to offset the effects of inflation on our cost structure.

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Substantially all of our cash operating expenses are denominated in reais and tend to increase with Brazilian inflation. Inflationary pressures might also hinder our ability to access foreign financial markets or might lead to further government intervention in the economy, including the introduction of government policies that could harm our business, results of operations and financial condition or adversely affect the market value of our shares and as a result, our Preferred ADSs and Common ADSs.

Exchange rate instability may adversely affect our business, results of operations and financial condition and the market price of our shares, the Preferred ADSs and the Common ADSs.

The Brazilian currency has been devalued periodically during the last four decades. Throughout this period, the Federal Government has implemented various economic plans and utilized a number of exchange rate policies, including sudden devaluations, periodic mini-devaluations during which the frequency of adjustments has ranged from daily to monthly, floating exchange rate systems, exchange controls and dual exchange rate markets. Although over long periods depreciation of the Brazilian currency generally has correlated with the rate of inflation in Brazil, devaluation over shorter periods has resulted in significant fluctuations in the exchange rate between the Brazilian currency and the U.S. dollar and currencies of other countries.

In 2012, the real depreciated 9.93% against the U.S. dollar. Considering the volatility the world economy is facing, no assurance can be given that the real will not continue to depreciate against the dollar. On December 31, 2012, the buy exchange rate for the U.S. dollar against the real was R$2.0476 to US$1.00. See “Item 3 Key Information — Exchange Rates.”

As of December 31, 2012, approximately 3.27% of our total indebtedness under loans, financings and debentures was denominated in currencies other than the real (92.61% of that being denominated in U.S. dollars). If the real depreciates against the U.S. dollar, our related financial expenses will increase and our results of operations and financial condition could be adversely affected. We recorded foreign exchange-related gain of R$13 million in 2010, foreign exchange-related losses of R$19 million in 2011 and foreign exchange-related losses of R$38 million in 2012. We also have entered into certain power purchase agreements that are dollar denominated. We cannot guarantee that derivatives instruments and the proceeds from our dollar-denominated purchase agreements will be sufficient to avoid an adverse effect on our business, results of operations and financial condition in the event of adverse exchange rate fluctuations. See “Item 11. Quantitative and Qualitative Disclosures about Market Risk—Exchange Rate Risk” for information about our foreign exchange risk hedging policy.

Changes in economic and market conditions in other countries, especially Latin American and emerging market countries, may adversely affect our business, results of operations and financial condition, as well as the market price of our shares, the Preferred ADS and the Common ADSs.

The market value of securities of Brazilian companies is affected to varying degrees by economic and market conditions in other countries, including other Latin American countries and emerging market countries. Although the economic conditions of such countries may differ significantly from the economic conditions of Brazil, the reactions of investors to events in those countries may have an adverse effect on the market value of securities of Brazilian issuers. Crises in other emerging market countries might reduce investor’s interest in securities of Brazilian issuers, including us. This could make it more difficult for us to access the capital markets and finance our operations in the future on acceptable terms or at all. Due to the characteristics of the Brazilian power industry (which requires significant investments in operating assets) and due to our financing needs, if access to the capital and credit markets is limited, we could face difficulties in completing our investment plan and refinancing our obligations which could adversely affect our business, results of operations and financial condition.

Political and economic instability in Brazil may affect us.

Periodically, allegations of unethical or illegal conduct have been made with respect to figures in the Brazilian government, including legislators and/or party officials. Further allegations on unethical or illegal conduct might be made at any time in relation to persons of the Brazilian government, including legislators and/or party representatives. If these events lead to a materially adverse perception of Brazil among investors, the trading value of our shares, the Preferred ADSs and the Common ADSs could decline, and our ability to access international markets could suffer. In addition, any political instability resulting from such events could cause us to re-assess our strategies if the Brazilian economy suffers as a result.

Risks Relating to the Preferred Shares, Common Shares, Preferred ADSs and Common ADSs

The preferred shares and Preferred ADSs generally do not have voting rights and the Common ADSs can only be voted by proxy by providing voting instructions to the depositary.

In accordance with the Brazilian Corporate Law and our by-laws, holders of our preferred shares, and, by extension, holders of our Preferred ADSs representing preferred shares, are not entitled to vote at our shareholders’ meetings, except in very limited circumstances. Holders of our Common ADSs representing common shares are not able to vote at our shareholders’ meetings, but

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rather vote by proxy by providing voting instructions to the depositary. Holders of our Preferred ADSs may also encounter difficulties in the exercise of certain rights, including limited voting rights. Under some circumstances, such as failure to provide the depositary with voting materials on a timely basis, holders of our Preferred ADSs and Common ADSs may not be able to vote by instructing the depositary.

Exchange controls and restrictions on remittances abroad may adversely affect holders of Preferred ADSs and Common ADSs.

You may be adversely affected by the imposition of restrictions on the remittance to foreign investors of the proceeds of their investments in Brazil and the conversion of reais into foreign currencies. Restrictions of this type would hinder or prevent the conversion of dividends, distributions or the proceeds from any sale of preferred shares or common shares from reais into U.S. dollars. We cannot guarantee that the Federal Government will not take similar measures in the future. See “Item 3. Key Information—Exchange Rates.”

Changes in Brazilian tax laws may have an adverse impact on the taxes applicable to a disposition of our shares, Preferred ADSs or Common ADSs.

Law No. 10,833 of December 29, 2003 provides that the sale of assets located in Brazil by a non-resident to either a Brazilian resident or a non-resident is subject to taxation in Brazil, regardless of whether the sale occurs outside or within Brazil. This provision results in the imposition of income tax on the gains arising from a disposition of our preferred shares or common shares by a non-resident of Brazil to another non-resident of Brazil. There is no judicial guidance as to the application of Law No. 10,833 and, accordingly, we are unable to predict whether Brazilian courts may decide that it applies to disposals of our Preferred ADSs and Common ADSs between non-residents of Brazil. However, in the event that the disposal of assets is interpreted to include a disposal of our Preferred ADSs and Common ADSs, this tax law would accordingly result in the imposition of withholding taxes on the disposal of our Preferred ADSs and Common ADSs by a non-resident of Brazil to another non-resident of Brazil.

Exchanging Preferred ADSs or Common ADSs for underlying shares may have unfavorable consequences.

The Brazilian custodian for the preferred shares and common shares must obtain an electronic certificate of foreign capital registration from the Central Bank to remit U.S. dollars from Brazil to other countries for payments of dividends, any other cash distributions, or to remit the proceeds of a sale of shares. If you decide to exchange your Preferred ADSs or Common ADSs for the underlying shares, you will be entitled to continue to rely, for five business days from the date of the exchange, on the depositary bank’s electronic certificate of registration in order to receive any proceeds distributed in connection with the shares. Thereafter, you may not be able to obtain and remit U.S. dollars abroad upon the disposition of the shares, or distributions relating to the shares, unless you obtain your own certificate of registration under CMN Resolution No. 2,689 of January 26, 2000, which entitles foreign investors to buy and sell on the Brazilian stock exchanges. If you do not obtain this certificate, you will be subject to less favorable tax treatment on gains with respect to the preferred or common shares. If you attempt to obtain your own certificate of registration, you may incur expenses or suffer significant delays in the application process. Obtaining a certificate of registration involves generating significant documentation, including completing and filing various electronic forms with the Central Bank and the Brazilian Securities Commission (Comissão de Valores Mobiliários), or the CVM. In order to complete this process, the investor will usually need to engage a consultant or attorney who has expertise in Central Bank and CVM regulations. Any delay in obtaining this certificate could adversely impact your ability to receive dividends or distributions relating to the preferred shares or common shares abroad or the return of your capital in a timely manner. If you decide to exchange your preferred shares or common shares back into Preferred ADSs or Common ADSs, respectively, once you have registered your investment in the preferred shares or common shares, you may deposit your preferred shares or common shares with the custodian and rely on the depositary bank’s certificate of registration, subject to certain conditions. See “Item 10. Additional Information—Taxation—Brazilian Tax Considerations.”

We cannot assure you that the depositary bank’s certificate of registration or any certificate of foreign capital registration obtained by you may not be affected by future legislative or other regulatory changes, or that additional Brazilian restrictions applicable to you, the disposition of the underlying preferred shares or common shares or the repatriation of the proceeds from disposition could not be imposed in the future.

The relative volatility and illiquidity of the Brazilian securities market may adversely affect our shareholders.

Investing in Brazilian securities, such as the preferred shares, common shares, Preferred ADSs or Common ADSs, generally involves a higher degree of risk than investing in securities of issuers from countries with more stable political and economic environments and such investments are generally considered speculative in nature. These investments are subject to certain economic and political risks, such as, among others:

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·changes to the regulatory, tax, economic and political environment that may affect the ability of investors to receive payment, in whole or in part, with respect to their investments; and

·restrictions on foreign investment and on repatriation of capital invested.

The Brazilian securities market is substantially smaller, less liquid, more concentrated and more volatile than major securities markets in the United States. This may substantially limit your ability to sell the shares underlying your Preferred ADSs or Common ADSs for the desired price and within the desired period. In 2012, the São Paulo Stock Exchange (BM&FBovespa S.A. — Bolsa de Valores, Mercadorias e Futuros), or BM&FBovespa, the only stock exchange in Brazil on which shares are traded, had an average market capitalization of approximately R$2.52 trillion, as of December 31, 2012,  and average daily trading volume of approximately R$7.2 billion. In comparison, the operating companies listed on the New York Stock Exchange, Inc., or the NYSE, had a market capitalization of approximately US$19.9 trillion as of December 31, 2012 and an average daily trading volume of approximately US$98.1 billion in 2012.

Shareholders may receive reduced dividend payments if our net income does not reach certain levels.

Under our by-laws, we must pay our shareholders a mandatory annual dividend equal to at least 50% of our net income for the preceding fiscal year, based on our financial statements prepared in accordance with IFRS, and also in accordance with the accounting practices adopted in Brazil, and holders of preferred shares have priority of payment. Our by-laws also require that the mandatory annual dividend we pay to holders of our preferred shares equal at least the greater of 10% of the par value of our shares or 3% of the stockholders equity of our shares, in the event that such amount is greater than the payment based on 50% of our net income. If we do not have net income or our net income is insufficient in a fiscal year, our management may recommend at the annual shareholders’ meeting in respect of that year that the payment of the mandatory dividend should not be made. However, under the guarantee of the State Government, our controlling shareholder, a minimum annual dividend of 6% of par value would in any event be payable to all holders of common shares and preferred shares issued up to August 5, 2004 (other than public and governmental holders) in the event that mandatory distributions have not been made in a given fiscal year. See “Item 8. Financial Information—Dividend Policy and Payments” for a more detailed discussion.

Holders of the Preferred ADSs and Common ADS and holders of our shares may have different shareholders’ rights than holders of shares in U.S. companies.

Our corporate governance, disclosure requirements and accounting standards are governed by our by-laws, by the Level 1 Differentiated Corporate Governance Practices of the BM&FBovespa, by the Brazilian Corporate Law and by the CVM. These regulations may differ from the legal principles that would apply if we were incorporated in a jurisdiction in the United States, such as Delaware or New York, or in other jurisdictions outside Brazil. In addition, the rights of an ADS holder, which are derivative of the rights of holders of our common or preferred shares, as the case may be, to protect their interests against actions by our board of directors and controlling shareholders, are different under Brazilian Corporate Law than under the laws of other jurisdictions. Rules against insider trading and self- dealing and other rules for the preservation of shareholder interests may also be different in Brazil than in the United States, potentially disadvantaging holders of the preferred shares, common shares, Preferred ADSs and Common ADSs.

The sale of a significant number of our shares or the issuance of new shares may materially and adversely affect the market price of our shares, Preferred ADSs and Common ADSs.

Sales of a substantial number of shares or the perception that such sales could take place could adversely affect the prevailing market price of our shares, the Preferred ADSs and the Common ADSs. As a consequence of the issuance of new shares or sales of shares by existing shareholders, the market price of our shares and, by extension, the Preferred ADSs and Common ADSs, may decrease significantly.

You may not be able to exercise preemptive rights with respect to our securities.

You may not be able to exercise the preemptive rights relating to the shares underlying your Preferred ADSs or Common ADSs unless a registration statement under the United States Securities Act of 1933, as amended, or the Securities Act, is effective with respect to those rights or an exemption from the registration requirements of the Securities Act is available. We are not obligated to file a registration statement with respect to the shares relating to these preemptive rights, and we cannot assure you that we will file any such registration statement. Unless we file a registration statement or an exemption from registration applies, you may receive only the net proceeds from the sale of your preemptive rights by the depositary or, if the preemptive rights cannot be sold, they will be allowed to lapse.

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Item 4.Information on the Company

Organization and Historical Background

We were organized in Minas Gerais, Brazil on May 22, 1952 as a sociedade por ações de economia mista (a state-controlled mixed capital company) with indefinite duration, pursuant to Minas Gerais State Law No. 828 of December 14, 1951 and its implementing regulation, Minas Gerais State Decree 3,710 of February 20, 1952. Our full legal name is Companhia Energética de Minas Gerais–CEMIG, but we are also known as CEMIG. Our headquarters are located at Avenida Barbacena, 1200, Belo Horizonte, Minas Gerais, Brazil. Our main telephone number is (55-31) 3506-3711.

In order to comply with legal and regulatory provisions pursuant to which we were required to unbundle our vertically integrated businesses, in 2004 we incorporated two wholly-owned subsidiaries of CEMIG: Cemig Geração e Transmissão S.A., referred to as Cemig Generation and Transmission, and Cemig Distribuição S.A., referred to as Cemig Distribution. Cemig Generation and Transmission and Cemig Distribution were created to carry out the activities of electricity generation and transmission, and distribution, respectively.

The following are our principal subsidiaries, which are consolidated in our financial statements as of and for the year ended December 31, 2012, all of which are incorporated in Brazil:

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Our main subsidiaries and jointly controlled entities include:

·Cemig Geração e Transmissão S.A., or Cemig Generation and Transmission (100% interest) which engages in electricity generation and transmission.

·Cemig Distribuição S.A., or Cemig Distribution (100% interest) which engages in electricity distribution.

·Light S.A. (“Light”) (jointly controlled, 26.06% direct and a 6.42% indirect interest in its total capital). The main holdings of Light are Light Energia S.A. (“Light Energia”), a generator of electricity, Light Serviços de Eletricidade S.A., an electricity distributor, and Light Esco Ltda., which operates in energy trading and energy efficiency. For further details, please see “—Acquisition of Interest in Light.”

·Companhia de Gás de Minas Gerais (“Gasmig”) (jointly controlled, 59.57% interest) which acquires, transports, distributes and sells natural gas.

·Trasmissora Aliança de Energia Elétrica S.A. (“TAESA”), formerly Terna Participações S.A., (jointly controlled, 43.36% indirect interest in its total capital), a holding company which operates in electricity transmission in 16 states of Brazil through the following companies, which it controls or in which it has stockholding interests:

nEmpresa de Transmissão do Alto Uruguai S.A. (“ETAU”) (holding 52.58% of the registered capital),

nBrasnorte Transmissora de Energia S.A. (holding 38.67% of the registered capital),

nATE II Transmissora de Energia S.A. (holding 100% of the registered capital),

nATE III Transmissora de Energia S.A. (holding 100% of the registered capital) and

nSão Gotardo Transmissora de Energia S.A (holding 100% of the registered capital)

Strategy

Our vision and goal is to “consolidate our position as the largest group in the Brazilian electricity sector in this decade, with a presence in the natural gas industry, and becoming a world leader in sustainability, admired by clients and recognized for our strength and performance.

In order to achieve our vision of the future and to follow our Long Term Strategic Plan, we have the following goals:

·              Strive to be a national leader in the markets we operate, with a focus on market share;

·              Strive for operational efficiency in asset management;

·              Be one of the most attractive companies for investors;

·              Be a benchmark in corporate management and governance;

·              Be innovative in the search for technological solutions for our business;

·              Be a benchmark in social, economic and environmental sustainability.

We have taken part in several transactions in the last year, which includes among others, the following:

Acquisition of Interest in Light

On May 12, 2011, our subsidiary Parati S.A. — Participações em Ativos de Energia Elétrica (“Parati”), an unlisted special purpose company, incorporated in October, 2008, which has as its corporate purpose the participation in the capital stock of other companies, domestic or foreign, as a partner or shareholder, acquired from Fundo de Investimento em Participações — PCP (“FIP PCP”) 54.08% of the total share capital of Redentor Energia S.A., which holds indirectly 13.03% of the share capital of  Light, through its subsidiary RME — Rio Minas Energia Participações S.A.

On July 7, 2011, Parati acquired from Enlighted Partners Venture Capital LLC 100% of its holdings in Luce LLC (“Luce”), owner of 75% of the unit shares of Luce Brasil Fundo de Investimento em Participações (“FIP Luce”), which holds indirectly 13.03% of the total shares of Light, through Luce Empreendimentos e Participações S.A. (“LEPSA”). With this acquisition Parati, which already indirectly held 7.05% of the total and voting capital of Light S.A., became indirect holder of 16.82% of the total and voting stock of Light.

On July 28, 2011, Parati acquired, from Fundação de Seguridade Social Braslight (“Braslight”) the totality of Braslight’s unit shares in FIP Luce. The amount received by Braslight for the sale of FIP Luce’s total shares was R$ 171,981,877.12. Thus Parati

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became the holder of 100% of the unit shares of FIP Luce, and, indirectly, the holder of the equivalent of 20.08% of the total and voting stock of Light.

As a result of the acquisition of the stockholding of FIP PCP, and in accordance with the rules of the Novo Mercado, the highest standard of corporate governance for companies listed in BM&FBovespa, Parati made a firm offer to acquire the shares held by the non-controlling stockholders of Redentor Energia S.A., granting them rights similar to tag-along rights.

On September 30, 2011, Parati acquired 46,341,664 shares held by minority stockholders, increasing its stockholding interest in Redentor Energia S.A. to 96.80% of its total capital. The remaining 3.20%, or 3,467,599 common shares, continued to be held by minority stockholders. After this transaction, Parati indirectly holds the equivalent of 25.64% of the total and voting stock of Light.

On March 14, 2013, Parati carried out a public offer for acquisition of shares aiming at the cancellation of Redentor Energia S.A.’s Listing Registration and its exit from the Novo Mercado segment. As a result of this public offer, Redentor Energia exits form the Novo Mercado segment, but it had to remain listed in BM&FBovespa.

On December 31. 2011, Parati held, directly, 25.64% of the registered capital of Light S.A. (“Light”). We held 25% of Parati’s share capital; and Redentor Fundo de Investimento em Participações held 75%. On December 31, 2011, we held a 32.47% total interest in Light, which included a direct 26.06% interest and an indirect 6.41% interest through Parati.

On February 10, 2012, Light approved the acquisition of 26,520,000 common shares (equivalent to a 51% equity interest) of Guanhães Energia S.A. (“Guanhães Energia”) by Light Energia for R$ 25.0 million (in May 2011 equivalent currency, adjusted by the  IPCA index until the date of closing of the transaction).The acquisition is conditional on prior approval by Aneel and will be submitted to the Brazilian antitrust authority (Conselho Administrativo de Defesa Econômica, or  CADE).

On August 28, 2012, Light Energia signed the final closing agreement with  Investminas Participações S.A. for the acquisition of 26,520,000  Class A common shares in Guanhães Energia S.A., equivalent to 51% of its share capital, for R$ 26,586,219.15.

On September 10, 2012 Light Energia issued 30 non-convertible debentures, with nominal unit value of R$1.0 million , maturing on June 4, 2026, for a total of R$30.0 million.

Acquisition of Interest in Transmission Companies from Abengoa

On November 30, 2011, TAESA, one of our jointly controlled companies, completed acquisition of interests of the ABENGOA Group (comprised of the companies disclosed below), as follows:

(i) 50% of the shares held by Abengoa Concessões Brasil Holding S.A. (“Abengoa”) in the share capital of União de Transmissoras de Energia Elétrica Holding S.A. (“UNISA”), the current name of Abengoa Participações Holding S.A., which holds 100%  of the total share capital of the transmission companies:

STE – Sul Transmissora de Energia S.A. (“STE”),

ATE Transmissora de Energia S.A. (“ATE”),

ATE II Transmissora de Energia S.A. (“ATE II”), and

ATE III Transmissora de Energia S.A. (“ATE III”, together with STE, ATE and ATE II, the “UNISA Transmission Companies”), and

(ii) 100% of the shares held by Abengoa and by Abengoa Construção Brasil Ltda. in the share capital of NTE — Nordeste Transmissora de Energia S.A.

Under the pricing provisions in the share purchase agreement with the Abengoa Group, the total amount paid by TAESA for the acquisition was R$1,163 million, with the proceeds of its fourth issue of promissory notes, financial settlement of which took place on November 29, 2011. The operating assets acquired include 1,579 miles of transmission lines, with a Permitted Annual Revenue (Receita Anual Permitida, or “RAP”) of R$509 million, representing an increase of R$309 million in TAESA’s RAP 2011/2012.

On March 16, 2012, TAESA, signed a share purchase agreement with Abengoa for acquisition of the remaining 50% of the shares held by Abengoa in UNISA, which in turn owns 100% of the share capital of the UNISA Transmission Companies. TAESA will pay a total amount of R$ 863.5 million in December 31, 2011 equivalent currency, for this acquisition. This amount will be updated by the accumulated variation of the Brazilian benchmark rate (“SELIC”)between the base date and the business day immediately preceding the date of completion of the transaction, when the actual acquisition of the shares by TAESA will take place. The acquisition price will be adjusted for remuneration and increases or reductions of capital that take place between the base date and the date of completion of the transaction.  Completion of the transaction and actual acquisition of the shares by TAESA will be subject to the fulfillment of certain suspensive conditions, which include: (i) approval by the General Meeting of Stockholders of TAESA; (ii)

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consent of the financing banks of the UNISATransmission Companies; and (iii) approval of the transaction by Aneel. Also, the transaction will be submitted to CADE, in accordance with Law 8884/94. On July 3, 2012, TAESA concluded the acquisition of the remaining 50% interest of Abengoa in UNISA (STE, ATE, ATE II and ATE III) for the amount of R$ 904 million. TAESA financed this acquisition by the issue of R$ 905 million in promissory notes.

Transfer of equity interests of the TBE transmission assets, held by Cemig and Cemig Generation and Transmission, to TAESA

On May 17, 2012, Cemig and TAESA signed a Private Contract for Investment in Transmission Assets, agreeing to transfer to TAESA the minority equity interests held by Cemig and Cemig Generation and Transmission in the share capital of the following holders of public electricity service concessions:

(i)Empresa Catarinense de Transmissão de Energia S.A.– ECTE;

(ii)Empresa Regional de Transmissão de Energia S.A. – ERTE;

(iii)Empresa Norte de Transmissão de Energia S.A. – ENTE;

(iv)Empresa Paranaense de Transmissão de Energia S.A. – ETEP;

(v)Empresa Amazonense de Transmissão de Energia S.A. – EATE; and

(vi)Empresa Brasileira de Transmissão de Energia S.A. – EBTE.

Within the scope of this stockholding restructuring, TAESA will disburse the amount of R$ 1,732 million, of which R$ 1,668 million  will be paid to Cemig and R$ 64 million will be paid to Cemig Generation and Transmission. These amounts will be updated by the CDI rate from December 31, 2011, less any dividends and/or interest on equity that is declared, whether paid or not. The amount involved was agreed by the companies based on technical valuations conducted by independent external evaluators.

This shareholding restructuring is in accordance with our strategic planning, which aims to consolidate our holdings in electricity transmission companies in a single corporate vehicle, and to optimize our ability to assess opportunities in future auctions of transmission lines and acquisition of transmission assets in operation.

Acquisition of the São Gotardo substation by TAESA in Aneel Auction 005/2012

On June 6, 2012, TAESA won Lot E of Aneel Auction 005/2012. TAESA created a special-purpose company (“SPC”) named São Gostardo Transmissora de Energia S.A. to which Aneel granted the right to commercial operation of the concession comprising two transmission functions within the São Gotardo 2 substation in the state of Minas Gerais. TAESA did not offer a discount in relation to the initial base RAP  of R$ 3,74 million and expects to complete construction within the period stipulated by Aneel, February 2014.

TAESA follow-on equity offering

On July 19, 2012, in a follow-on equity offering, TAESA issued 24 million units (each presenting one common share and two preferred shares), at R$ 65 per unit..On August 20, 2012, the bookrunners exercised the overallotment option and TAESA issued an additionl 3 million units, totaling 27 million units issued in the follow-on equity offering. The share capital of TAESA was increased, within the limit of its authorized capital, in the amount of R$1.755 billion, by issuance of 81 million new shares: 27 million common and 54 million preferred shares. Under Brazilian Corporate Law, and our by-laws, existing stockholders did not have a right of first refusal in this subscription. As a result of the follow-on equity offering, Cemig Generation and Transmission’s holding in TAESA was diluted, from 56.69% to 43.36%. The mentioned operation gave rise to a gain in the amount of R$ 259, reported in our profit and loss account for the third quarter of 2012.

On December 4, 2012, TAESA underwent a three-for-one split of all its shares: each share (whether or not represented by or included in a deposit certificate (or “unit”)) became three shares of the same type.  The split had no effect on TAESA’s equity, on the ratio of common to preferred shares, or on any feature or attribute of any share.. After the split, TAESA has 1,033,496,721 shares: 691,553,133 common shares and 341,943,588 preferred shares; and there is no change in the total value of TAESA’s share capital.

Acquisition of Interest in Renova

Renova Energia S.A. (“Renova”) is a company generating electricity from renewable sources focused on wind farms and small hydroelectric plants (PCHs). Renova prospects for, develops and implements renewable energy enterprises and is currently the only company listed on the BM&FBovespa dedicated to working with alternative energy sources in Brazil. It has created the largest wind farm complex in Brazil, located in the semi-arid region of the Brazilian state of Bahia, and sold a total of 690MW of installed electricity generation capacity in the reserve energy auctions of 2009 and 2010, the A–3 auction of 2011 and the A-5 auction of 2012.

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On August 19, 2011 Light, through its subsidiary Light Energia, subscribed 50,561,797 of Renova’s common shares. As a result, Light Energia holds 34.85% of Renova’s common shares and 25.9% of its total capital. The transaction included a private placement of Renova’s shares in the approximate amount of R$ 360.0 million. Renova1s minority shareholders participated in the private placement, resulting in a total capital injection of R$ 376.0 million.

The common shares subscribed by Light Energia are part of the controlling stockholding block of Renova, and represent half of the shares comprising the control block, with the same rights and preferences attributed to the other common shares issued by Renova. To make the transaction possible, RR Participações S.A. (“RR Participações”) and certain stockholders of Renova waived their right of first refusal in favor of Light Energia. Light Energia and RR Participações entered into a stockholders’ agreement which regulated the exercise of the right to vote, purchase and sale of shares issued by the Renova held by the parties, and their rights and obligations as stockholders of the Renova. Light has experience in building and operating generation projects, and sale and placement of electricity. We understand that this combination will enable Renova to position itself as one of the largest players in wind generation in Latin America, with unique and extremely attractive characteristics. The agreement also contains a commitment by Light to purchase 400MW of installed power capacity provided by Renova’s wind projects. The companies further have the right of first refusal in the purchase or sale, as applicable, of wind energy in long-term The principal purpose of this acquisition is to accelerate the growth of Renova through a combination of its own technical capacity and pioneering experience in development of new projects and business with our own experience and contracts entered into in the Free Market.

On June 22, 2012, the Contract for Subscription of Units issued by Renova, was entered into between BNDES Participações S.A. (“BNDESPar”), Renova, Light, Light Energia and RR Participações, governing the investment by BNDESPar in Renova. The contract is for a capital increase in Renova, to be decided at a later date, in the total amount of up to R$ 314,700,407.85, at the price of R$ 9.3334 per share. The entry of BNDESPar into Renova provides increased negotiating and financial capacity for it to make the investments planned up to that time. Due to this operation, as of 31 December, 2012, Light’s interest in Renova was 21.99%.

The table below shows the Renova portfolio of projects.

Contracted Capacity (MW)	1090
LER 2009	294
LER 2010	162
A-3 2011	212
PPA Free Market	400
A-5 2012	22,4
Certified Projects (MW)	2200
Developing Projects (MW)	2400

In July, 2012, Renova Energia set up Alto Sertão I, a wind farm complex, located among the cities of Caetité, Igaporã and Guanambi, in the Southwest region of the state of Bahia. Alto Sertão I  is considered the largest wind farm complex in Latin America, with an installed capacity of 294 MW, enough to supply 540,000 homes, the complex had an investment of R$1.2 billion and consists of 14 wind farms and 184 turbines.

Acquisition of Interest in Guanhães Energia

On February 10, 2012, Light approved the acquisition of 26,520,000 common shares (equivalent to a 51% equity interest) of Guanhães Energia S.A. (“Guanhães Energia”) by Light Energia for R$ 25.0 million (in May 2011 equivalent currency, adjusted by the  IPCA index until the date of closing of the transaction).The acquisition is conditional on prior approval by Aneel and will be submitted to the Brazilian antitrust authority (Conselho Administrativo de Defesa Econômica, or  CADE).

On August 28, 2012, Light Energia signed the final closing agreement with  Investminas Participações S.A. for the acquisition of 26,520,000 Class A common shares in Guanhães Energia S.A., equivalent to 51% of its share capital, for R$ 26.5 million. For more information regarding Guanhães Energia, see “Expansion of Generation Capacity” section.

Acquisition of 9.77% interest in Norte Energia S.A.: the Belo Monte Hydroelectric Plant

The Belo Monte Hydroelectric Plant (“Belo Monte”) is the largest plant currently under construction in the world, and when completed will have installed capacity of 11,233 MW, with Assured Energy of 4,571 MW average. The commercial operation is planned to start in February 2015, and the concession period is 35 years. The concession for the construction and operation of the Belo Monte Hydroelectric Plant, on the Xingu River, in the Brazilian state of Pará, belongs to Norte Energia S.A. (“Norte Energia”), which won the auction held in April 2010.

The Northern region of Brazil is the principal expansion frontier for generation of hydroelectric energy in Brazil, and more than 60% of the potential for hydroelectric expansion is still available. Therefore, we understand that the participation in this project has strategic value. The Belo Monte Hydroelectric Plant is the second project in the region in which Cemig Generation and Transmission is participating, the first being its 10% interest in the consortium building the Santo Antônio Hydroelectric Plant in the Brazilian State of Rondônia.

Amazônia Energia Participações S.A. (“Amazônia Energia”) is a special-purpose company in which the stockholders are: Light S.A., with 51% of the voting stock and 25.5% of the total stock; and Cemig Generation and Transmission, with 49% of the

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voting stock and 74.5% of the total stock. On October 25, 2011, Amazônia Energia signed share purchase agreements with six companies that held, in aggregate, an interest of 9.77% in Norte Energia, as follows: (i) Construtora Queiroz Galvão S.A.: 2.51%; (ii) Construtora OAS Ltda.: 2.51%; (iii) Contern Construções e Comércio Ltda.: 1.25%; (iv) Cetenco Engenharia S.A.: 1.25%; (v) Galvão Engenharia S.A.: 1.25%; and (vi) J. Malucelli Construtora de Obras S.A.: 1%.

The acquisition price corresponds to the amount of the injections of capital made by the vendors, adjusted by the IPCA index up to October 26, 2011, in the amount of R$ 118.69 million.

The transaction involving the participation of Amazônia Energia as a stockholder of Norte Energia was approved by the Extraordinary General Meeting of Norte Energia and by our and Light’s Boards of Directors. The Brazilian electricity regulator, Aneel, has been informed about the transaction, and it has been submitted to CADE, in accordance with Law 8884/94.

The transaction adds 818 MW of generation capacity to our total holdings, increasing our market share in Brazilian electricity generation from 7% to 8%; and adds 280 MW to the total generation capacity of Light.

Advantages of this transaction include the following: (i) the principal contracts for building works and equipment have been signed; (iii) the principal risks associated with the project have been considerably mitigated; (ii) future injections of capital will be diluted over nine years, and will use the cash flow generated by the project itself during the last three of those years; (iv) the environmental costs have been defined; and (v) all of the sales transactions for the electricity have already been established.

This acquisition will not have any effect on the policy for payment of dividends to our stockholders.

Increase of stockholding in Gasmig

On December 27, 2011, our Board of Directors authorized the acquisition of 10,781,736 nominal common shares and 7,132,773 nominal preferred shares, representing 4.38% of the total capital of Companhia de Gás de Minas Gerais — Gasmig, which belonged to the State of Minas Gerais, for R$ 67.2 million, corresponding to a price per share of approximately R$3.75, lately adjusted to the value given by an independent valuation opinion prepared by a specialized institution, which resulted in a valuation of the holding acquired at R$65. For more information, see the section “14. Investment”, in the Financial Statements.

Acquisition by Cemig of an equity interest in Gás Brasiliano (GBD)

On February 8, 2012, CEMIG signed an investment agreement with Petrobrás Gás S.A — Gaspetro and Gás Brasiliano Distribuidora S.A (“GBD”), to subscribe common shares representing 40% of the share capital of GBD, subject to certain prior conditions. GBD is a natural gas distribution company that distributes to consumers in the residential, industrial, and commercial sectors, the automobile industry, co-generation plants, and thermal generation plants.

Increase in the interest held by Cemig Capim Branco Energia S.A. in the Capim Branco Energia Consortium

At a board meeting on December 28, 2012, Cemig authorized its wholly-owned subsidiary, Cemig Capim Branco Energia S.A.  (“Cemig Capim Branco”), to accept an offer made by Suzano Papel e Celulose S.A. and its subsidiaries (“Suzano”), on December 27, 2012, for acquisition by Cemig Capim Branco of its proportional interest in the 17.89% interest held by Suzano in the Capim Branco Energia Consortium (“the Consortium”), and also stated the intention to acquire any shares remaining in the event that the other consortium members did not exercise their rights of first refusal, as specified in the Consortium Constitution Agreement. Suzano’s interest in the Consortium proportionately represents about 81MW of installed capacity, at the Amador Aguiar I and II hydroelectric plants, and assured average power of 51MW. The members of the Consortium other than Suzano are Cemig Capim Branco, with 21.05% Vale S.A., with 48.42%; and Votorantim Metais Zinco S.A., with 12.63%. On March 12, 2013 Cemig Capim Branco signed the final contract for the acquisition of 30.30% of Suzanos’s 17.89% interest in the Consortium. The total price agreed, subject to any adjustments, for Suzano’s 17.89% interest in the Consortium was R$ 320 million. Of this total, the proportional interest to be acquired by Cemig Capim Branco represents a total of approximately R$97 million. The transaction is subject to completion, and approvals by Aneel and CADE.

Capital Expenditures

Capital expenditures for the years ended December 31, 2012, 2011 and 2010 in millions of reais, were as follows:

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	Year ended December 31,
	2012	2011	2010
Distribution network	1,446	1,857	2,050
Power Generation	804	972	359
Transmission network	446	1,030	1,581
Others	834	121	132
Total capital expenditures	3,530	3,980	4,122

Recent changes in the regulation of the energy sector, especially those introduced to the generation and transmission business by Law No. 12,783, and Cemig Distribution’s tariff review (held in April 2013) have required more precise budget planning. As of the date of this report, our Capital Expenditure and Investment Plan for 2013 had not yet been approved by us.

We expect to fund our capital expenditures in 2013 mainly from our cash flow from operations and, to a lesser extent, through financing. We expect to finance our expansion and projects by commercial bank loans and by issuing debentures in the local market.

Business Overview

General

We run a business related to generation, transmission, distribution and sale of electricity, gas distribution, telecommunications and the provision of energy solutions.

Cemig

Cemig engages in transactions for the purchase and sale of electricity through its subsidiaries. Total resources used in the year 2012 amounted to 83,912  GWh, an amount that is 2.9% higher than the resources used in the previous year. The amount of energy produced in 2012 was 38,433 GWh, which represented an increase of 12.7% over 2011 and the amount of energy purchased totaled 45,479 GWh, which represented an decrease of  4.1% over 2011. This refers to the energy purchased form Itaipu 8,422 GWh and energy purchased by CCEE and other companies (37,057 GWh).

The energy traded in 2012 was 48,487 GWh, an amount 1.34% higher than traded in 2011, and 94.9% of that value (46,015 GWh) was traded to final consumers, both captive and free.

The total losses of energy in the core network and distribution networks totaled 6,317 GWh, which corresponds to 7.5% of total resources and 10.6% higher than the losses in 2011 (5,712 GWh).

The table below shows the breakdown of resources and power requirements by Cemig traded in the last three years.

CEMIG’S ELECTRIC ENERGY BALANCE (6)

(GWh)	Year ended December 31,
	2012	2011	2010
RESOURCES	83,912	81,523	77,752
Electricity generated by CEMIG (1)	35,382	31,276	30,361
Electricity generated by auto-producers	1,100	997	980
Electricity generated by Ipatinga	309	308	300
Electricity generated by Barreiro	82	60	65
Electricity generated by Sá Carvalho	405	356	380
Electricity generated by Horizontes	54	53	80
Electricity generated by Cemig PCH	70	51	58
Electricity generated by Rosal Energia	249	251	310
Electricity generated by Amador Aguiar	656	580	614
Electricity generated by Cachoeirão (5)	126	163	134
Electricity bought from Itaipu	8,422	8,475	8,590
Electricity bought from CCEE and other companies (2)(3)	37,057	38,953	35,880

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REQUIREMENTS	83,912	81,523	77,752
Electricity delivered to final consumers (4)	46,015	45,346	43,272
Electricity delivered to auto-producers	994	991	993
Electricity delivered by Ipatinga	309	308	300
Electricity delivered by Barreiro	97	100	99
Electricity delivered by Sá Carvalho	476	498	496
Electricity delivered by Horizontes	81	83	85
Electricity delivered by Cemig PCH	109	115	121
Electricity delivered by Rosal Energia	263	262	263
Electricity delivered by Cachoeirão (5)	143	143	143
Electricity delivered to the CCEE and other companies(2)(3)	29,108	27,965	26,264
Losses	6,317	5,712	5,716

(1)Discounting the losses attributed to generation (418 GWh in 2012) and the internal consumption of the generating plants.

(2)This amount refers to contracts, purchases and sales of electricity under the CCEE, including the Energy Reallocation Mechanism (Mecanismo de Realocação de Energia).

(3)Includes bilateral contracts with other agents of the CCEE.

(4)Includes electricity delivered to consumers outside the concession area.

(5)Includes 100% of electricity produced by Cachoeirão Hydro Power Plant. CEMIG has a 49% interest in the consortium, and is responsible for the sale of 100% of the physical guarantee of this Small Hydro Plant.

(6)It does not include Light, which manages its own electric energy balance.

Light

Total energy consumption in the concession area of Light Serviços de Eletricidade S.A. (“Light SESA”), which is controlled by our subsidiary Light S.A., (including captive customers and transport of Free Consumers) came to 23,384 GWh in 2012, a 2.0% increase over 2011. The commercial  segment, which increased by 9.1%, was the best performer.

In 2012, the amount of energy produced was 4,290 MWh a volume 5.0% below the 4,518 MWh generated in 2011. All of Light’s energy is produced by hydropower plants, with a total capacity of 855MW (excluding energy produced by other companies).

In 2012, a total of 5,372.8 GWh was sold, a 2.7% decline from the amount sold in 2011. This result was primarily impacted by the spot market sales due to the poor hydrological conditions during 2012, especially in the last quarter. In the captive market (ACR), volume was down 2.0% from the previous year due to the reinstatement of Mechanism for the Offsetting of Surpluses and Deficits (MCSD). The reinstatement of MCSD resulted in the termination of contracts in the captive market (ACR), which offset the 20.5% increase in sales to the free market (ACL).

The table below shows the energy generated and sold by Light Energia for the periods and in the markets indicated below.

LIGHT ENERGIA (GWh)	4Q 2012	4Q 2011	%	2012	2011	%
ACR Sales	1,069.4	1,082.0	-1.2%	4,103.0	4,185.7	-2.0%
ACL Sales	204.7	173.0	18.3%	746.6	619.8	20.5%
Spot Sales (CCEE)	(4.9)	125.4	-	523.2	717.5	-27.1%
Total	1,269.2	1,380.4	-8.1%	5,372.8	5,523.0	-2.7%

In accordance with Aneel’s calculation methodology, Light’s commercial, or non-technical, losses in the year ended December 2012 totaled 6,007 GWh, representing 45.4% of billed energy in the low-voltage market, 2.3 and 5.0 percentage points up from September 2012 and December 2011, respectively. For more information, see “Energy Losses” section.

Light SESA’s total energy losses amounted to 8,584 GWh, or 23.6% of the grid load, in 2012, 1.9% up from 2011, due to high temperatures recorded during 2012, especially in the fourth quarter, that caused an increase of electric power theft by low-income consumers, and primarily by the initiative implemented at the beginning of the year related to the termination of contracts with clients presenting long-term default in areas where traditional collection initiatives are not effective, pursuant to ANEEL Resolution 414.

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LIGHT’S ELECTRIC ENERGY BALANCE

	Year ended December 31,
	2012	2011	2010
Energy Balance (GWh)
Grid Load	36,409	34,983	35,201
Energy transported to utilities	2,637	2,901	3,047
Energy transported to free consumers*	5,018	4,664	5,206
Own Load	28,755	27,418	26,948
Captive market consumption	20,054	19,877	19,459
Low Voltage Market	13,207	12,985	12,630
Medium Voltage Market	6,847	6,891	6,829
Losses + Non Billed Energy	8,701	7,542	7,489

* Including CSN and CSA

Generation

According to Aneel, at December 31, 2012, we were the fourth largest electric power generation group in Brazil as measured by total installed capacity. At December 31, 2012, we generated electricity at 64 hydroelectric plants, three thermoelectric plants and three wind farms and had a total installed generation capacity of 7,038 MW of which hydroelectric plants accounted for 6,805 MW, thermoelectric plants accounted for 184 MW and wind farms accounted for 49 MW.  Eight of our hydroelectric plants accounted for approximately 77% of our installed electric generation capacity in 2012.  During the year ended December 31, 2012, we recorded expenses totaling R$252.58 million relating to transmission charge payments made to the ONS and to transmission concession holders. See “—The Brazilian Power Industry” and “Item 5. Operating and Financial Review and Prospects.”

Transmission

We are engaged in the electric power transmission business, which consists of transporting electric power from the facilities where it is generated to the distribution networks for delivery to final users. We transport energy produced at our own generation facilities and that we purchase from Itaipu, and other sources, as well as the energy for the interconnected power system and other concessionaires. Our transmission network is comprised of power transmission lines with a voltage capacity equal to or greater than 230 kV and is part of the Brazilian Grid regulated by the ONS. See “—The Brazilian Power Industry.” As of December 31, 2012, our transmission network consisted of approximately  40 miles of upper 525 kV lines, 3,042 miles of 500 kV lines, 135 miles of 440kV lines, 1,286 miles of 345 kV lines and 1,343 miles of 230 kV lines, which were distributed, mainly, among the following companies :

·Cemig Generation and Transmission: 1,352 miles of 500 kV lines, 1,222 miles of 345 kV lines and 490 miles of 230 kV lines located in Minas Gerais.

·TAESA: Our proportional share of TAESA transmissions lines includes 1,159 miles of 500 kV lines, 135 miles of 440 kV lines and 303 miles of 230 kV lines in 16 different Brazilian States.

·TBE: Our proportional share of TBE transmissions lines includes 40 miles of upper 525 kV lines, 531 miles of 500 kV lines, one mile of 345 kV lines and 456 miles of 230 kV lines.

·Transmineiras* and  Centroeste: Our proportional share of Transmineiras and Centroeste transmissions lines includes  63 miles of 345 kV lines and 9 miles of 230 kV lines.

·Light: Our proportional share of Light transmissions lines includes 23  miles of 230 kV lines.

·Transchile operates a total of 62 miles of 220 KV lines (the Charrúa – Nueva Temuco line) in the country of Chile.

* Transmineiras includes Transleste, Transudeste and Transirapé.

Distribution

Through Cemig Distribution, we have four distribution concession agreements in the State of Minas Gerais that grant us rights to supply electricity to consumers in that area, including consumers that may be eligible, under the legislation, to become Free Consumers (consumers with demand equal to or greater than 3 MW, or consumers with demand equal to or greater than 500 kW from

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alternative energy sources, such as wind, biomass or small hydroelectric plants). The concession area of Cemig Distribution covers approximately 219,103 square miles, or 96.7% of the territory of the state. As of December 31, 2012, through Cemig Distribution, we owned and operated approximately 308,466 miles of distribution lines, through which we supplied 24,633 GWh to approximately 7.5 million end-consumers.

Through Light Serviços de Eletricidade S.A. (“Light SESA”), which is controlled by our subsidiary Light S.A., as of December 31, 2012, we owned and operated 37 thousand miles of distribution lines, through which we supplied 23,384 GWh to approximately 4 million end-consumers, which represented a 2.0% increase in consumption over 2011. The concession area of Light SESA covers 31 cities of the State of Rio de Janeiro.

In 2012, a total of 5,018 GWh was carried and delivered by the electricity distribution system to the Free Consumers. The total amount of electricity supplied was 23,384 GWh, of which 35% was supplied to residential consumers, 29% to commercial consumers, 15% to other consumers, 14% to Free Consumers and 7% to industrial consumers.

Light S.A., with the operation of the Paracambi Small Hydro Plant (SHP) in May 2012, and Renova Energia, with the operation of its  first wind farm in July 2013, combined to increase their collective installed capacity from 866 MW in 2011 to 942 MW in 2012.

Other Businesses

While our main business consists of the generation, transmission and distribution of electricity, we also engage in the following businesses: (i) distributing natural gas in Minas Gerais through our subsidiary, Gasmig, (ii) telecommunications through our consolidated subsidiary Cemig Telecomunicações S.A.; (iii) national and international energy solutions consulting business through our subsidiary Efficientia S.A.,; and (iv) implementation and management of systems for electricity sector companies through our subsidiary Axxiom Soluções Tecnológicas S.A.; (v) exploitation of natural gas through six consortia, listed as follows: (a) Consórcio de Exploração SF-T-104, (b) Consórcio de Exploração SF-T-114, (c) Consórcio de Exploração SF-T-120, (d) Consórcio de Exploração SF-T-127, (e) Consórcio de Exploração REC-T-163, and (f) Consórcio de Exploração POT-T-603, formed with several partners; and (vi) sale and trading of electricity, structuring and intermediating purchases and sale transactions, buying and selling electricity in the Free Market through our wholly-owned subsidiaries Cemig Trading S.A. and Empresa de Serviços de Comercialização de Energia Elétrica S.A.

Revenue Sources

The following table shows the revenues attributable to each of our principal revenue sources, in millions of reais, for the periods indicated:

	Year ended December 31,
	2012	2011	2010
Electricity sales to final consumers	16,671	14,955	13,219
Revenue from wholesale supply to other concession holders and PROINFA	1,942	1,613	1,469
Revenue from use of the basic electricity distribution system (TUSD)	2,216	1,978	1,658
Revenue from use of the transmission system	1,675	1,407	1,141
Indemnity transmission revenues	192	-	-
Construction revenues	1,631	1,541	1,341
Revenue from sale on the spot market	427	269	133
Other operating revenues	1,324	983	924
Tax on revenues	(7,618)	(6,997)	(6,095)
Total	18,460	15,749	13,790

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Power Generation and Trading

Overview

The following table sets forth certain operating information concerning our electric power generation plants as of December 31, 2012

	Installed	Assured	Year	Installed	Year	Cemig’s
	Capacit	Energy (1)	Commenced	Capacity	Concession or	Interest
Facility
	(MW)	(average MW)	Operations	% of Total	Authorization
					Expires
Hydroelectric Plants
São Simão	1,710.00	1,281.00	1978	23.40%	jan/15	100%
Emborcação	1,192.00	497.00	1982	16.31%	jul/25	100%
Nova Ponte	510.00	276.00	1994	6.98%	jul/25	100%
Jaguara	424.00	336.00	1971	5.80%	aug/13	100%
Miranda	408.00	202.00	1998	5.58%	dec/16	100%
Três Marias	396.00	239.00	1962	5.42%	jul/15	100%
Volta Grande	380.00	229.00	1974	5.20%	feb/17	100%
Irapé	360.00	206.30	2006	4.93%	feb/35	100%
Aimorés	161.70	84.28	2005	2.21%	dec/35	49%
Salto Grande	102.00	75.00	1956	1.40%	jul/15	100%
Funil	88.20	43.61	2002	1.21%	dec/35	49%
Queimado	86.63	47.85	2004	1.19%	jan/33	83%
Sá Carvalho	78.00	58.00	1951	1.07%	dec/24	100%
Rosal	55.00	30.00	1999	0.75%	may/32	100%
Itutinga	52.00	28.00	1955	0.71%	jul/15	100%
Amador Aguiar I	50.53	32.63	2006	0.69%	aug/36	21.05%
Baguari	47.60	27.27	2009	0.65%	aug/41	34%
Camargos	46.00	21.00	1960	0.63%	jul/15	100%
Amador Aguiar II	44.21	27.58	2007	0.60%	aug/36	21.05%
Porto Estrela	37.33	18.60	2001	0.51%	jul/32	33.33%
Igarapava	30.45	19.72	1999	0.42%	dec/28	14.5%
Pai Joaquim	23.00	2.41	2004	0.31%	apr/32	1
Piau	18.01	13.53	1955	0.25%	jul/15	100%
Gafanhoto	14.00	6.68	1946	0.19%	jul/15	100%
Cachoeirão	13.23	8.02	2008	0.18%	jul/30	49%
Paracambi	12.25	9.57	2012	0.17%	feb/31	49%
Pipoca	9.80	5.83	2010	0.13%	sep/31	49%
Peti	9.40	6.18	1946	0.13%	jul/15	100%
		2.15

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Poço Fundo	9.16	5.79	1949	0.13%	aug/25	100%
Tronqueiras	8.50	4.14	1955	0.12%	jul/15	100%
Joasal	8.40	5.20	1950	0.11%	jul/15	100%
Salto Voltão	8.20	6.63	2001	0.11%	oct/30	100%
Martins	7.70	2.52	1947	0.11%	jul/15	100%
Cajuru	7.20	3.48	1959	0.10%	jul/15	100%
São Bernardo	6.82	3.42	1948	0.09%	aug/25	100%
Paraúna	4.28	1.90	1927	0.06%	N/A	100%
Pandeiros	4.20	1.87	1957	0.06%	sep/21	100%
Paciência	4.08	2.36	1930	0.06%	jul/15	100%
Marmelos	4.00	2.88	1915	0.05%	jul/15	100%
Other SHP (3)	24.08	11.11	N/A	0.33%	N/A	N/A
Thermoelectric Plants
Igarapé	131.00	71.30	1978	1.86%	aug/24	100.0%
Ipatinga	40.00	40.00	1986 (2)	0.57%	dec/14	100.0%
Barreiro	12.90	11.37	2004	0.18%	apr/23	100.0%
Wind Farms
Praias de Parajuru	14.11	4.11	2012	0.20%	sep/32	49.0%
Praia de Morgado	14.11	6.47	2011	0.20%	dec/31	49.0%
Volta do Rio	20.58	9.02	2011	0.29%	dec/31	49.0%
Light Hydroelectric Plants
Fonte Nova	34.40	27.10	1940	0.49%	jul/29	32.5%
Paracambi	12.30	9.60	2012	0.17%	sep/31	51.0%
Ilha dos Pombos	48.80	30.00	1924	0.69%	jul/29	32.5%
Nilo Peçanha	99.00	87.30	1940	1.41%	jul/29	32.5%
Pereira Passos	26.10	13.30	1962	0.37%	jul/29	32.5%
Santa Branca	14.60	8.30	1999	0.21%	jul/29	32.5%
Cachoeira da Lixa	14.80	8.26	2008	0.21%	dec/33	7.2%
Colino 1	11.00	7.34	2008	0.16%	dec/33	7.2%
Colino 2	16.00	10.49	2008	0.23%	dec/33	7.2%
TOTAL	7,023.66	4,279.27	-	100%	-	-

(1)   Assured Energy is the plant’s long-term average output, as established by the Ministry of Mines and Energy (MME) in accordance with studies conducted by the EPE. Calculation of Assured Energy considers such factors as reservoir capacity and connection to other power plants. Contracts with final consumers and other concessionaires do not provide for amounts in excess of a plant’s Assured Energy. MME Resolution 303/2004 changed the term Assured Energy to Physical Guarantee.

(2)   Indicates our date of acquisition.

(3)   Corresponds to 17 Small Hydroelectric Power Plants: Anil, Bom Jesus do Galho, Dona Rita, Jacutinga, Lages, Luiz Dias, Machado Mineiro, Pissarrão, Poquim, Rio de Pedras, Salto de Morais, Salto do Passo Velho, Salto do Paraopeba, Santa Luzia, Santa Marta, Sumidouro and Xicão.

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The following tables set forth certain additional operating information pertaining to our electricity generation operations as of the dates indicated:

Voltage of Connection Lines	Circuit Length of Generation Lines in Miles (from power plants to generation substations)
	As of December 31,
	2012	2011	2010
500 kV	7	7	7
345 to 230 kV	108	108	108
161 to 138 kV	114(1)	112	112
69 to 13.8 kV	187	187	187
Total	416	414	63

	Step-Down Transformation Capacity(2) of Generation Substations
	As of December 31,
	2012	2011	2010
Number of step-down substations	64	63	63
MVA	7,445	7,416	7,416	(3)

(1)           The circuit length of our 138 KV connection lines increased in 2012 because the Paracambi small Hydroelectric plant began its operations.

(2)           This amount does not include the Light acquisition.

(3)           Step-down transformation capacity refers to the ability of a transformer to receive energy at a certain voltage and release it at a reduced voltage for further distribution.

Generation Assets

We have incorporated the following subsidiaries in the State of Minas Gerais and other states of Brazil to operate certain of our generation facilities and to hold the related concessions:

Cemig Generation and Transmission S.A. — As of December 31, 2012, we have electricity generation capabilities in 57 hydroelectric plants, three thermoelectric plants and three wind farms, which totals a generation capacity of 6,761 MW, value of which hydroelectric plants accounted for 6,528 MW, thermoelectric plants accounted for 184 MW and wind farms accounted for 49 MW.

In addition to our own plants, Cemig Generation and Transmission participates in the following consortia:

·Igarapava Hydroelectric Power Plant — We have a 14.5% interest in this enterprise and our partners are Vale S.A. (38.2%), Votorantim Metais Zinco S.A. (23.9%), Companhia Siderúrgica Nacional S.A. (17.9%) and Anglogold Ashanti Córrego do Sítio Mineração S.A. (5.5%).

·Queimado Hydroelectric Power Plant — Our partner in this project is CEB Participações S.A. (CEBPar), a subsidiary of Companhia Energética de Brasília, or CEB, a state-controlled electricity company. As per the second Amendment to Concession Contract 006/1997, executed on July 17, 2009, CEB has a 17.5% interest and we have the remaining 82.5%.

·Aimorés Hydroelectric Power Plant —We have a 49% interest in this enterprise and our partner, Vale S.A., has the remaining 51% interest.

·Funil Hydroelectric Power Plant — We have a 49% interest in this enterprise and our partner, Vale S.A., has the remaining 51% interest.

·Porto Estrela Hydroelectric Plant — We have a 33.3% interest in this enterprise and our partners are Vale S.A. (33.3%) and Companhia de Tecidos Norte de Minas — Coteminas (33.3%).

Light S.A. — At December 31, 2012, we generated electricity at five hydroelectric plants with a total installed generation capacity of 866 MW.

Renova Energia S.A. — At December 31, 2012, we generated electricity at three small hydro plants with a total installed generation capacity of  42 MW. Usina Térmica Ipatinga S.A. — We operate the Ipatinga Thermoelectric Power Plant through our subsidiary.

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Usina Térmica Ipatinga S.A. — This plant is an SPP (self power producer) installed and operated within the premises of Usinas Siderúrgicas de Minas Gerais S.A.—USIMINAS, or Usiminas, a large Brazilian steel manufacturer. The plant supplies power to a large steel mill owned by Usiminas, located in eastern Minas Gerais. The plant currently has an installed capacity of 40 MW, generated by two units that began operating in 1986 and that use blast furnace gas as fuel.

Sá Carvalho S.A. — We operate the Sá Carvalho Hydroelectric Power Plant, located on the Piracicaba River in the municipality of Antônio Dias, in the State of Minas Gerais, through our subsidiary Sá Carvalho S.A.. The plant currently has an installed capacity of 78 MW.

Rosal Energia S.A. — In December 2004 we bought the Rosal hydroelectric plant, which has installed capacity of 55 MW, from Caiuá Serviços de Eletricidade S.A., or Caiuá, for a payment of R$134 million. The Rosal plant, the sole asset of Rosal Energia, is located on the Itabapoana River, which runs along the border between the States of Espírito Santo (Municipality of Guaçuí) and Rio de Janeiro (Municipality of Bom Jesus de Itabapoana).

Cemig Capim Branco Energia S.A. — We incorporated Cemig Capim Branco Energia S.A. (21.1%) to develop the Capim Branco Generating Complex in partnership with Vale S.A. (48.4%), a mining company, Comercial e Agrícola Paineiras (17.9%), an agricultural company, and Votorantim Metais  Zinco S.A. (12.6%), or VMZ, a metallurgical company. On March 16, 2007, Aneel published Ruling No. 683 approving the change of the name of the Capim Branco Generating Complex to the Amador Aguiar Generating Complex. The project consists of the Amador Aguiar I and Amador Aguiar II Hydroelectric Power Plants, with installed capacity of 240 MW and 210 MW, respectively.

Horizontes Energia S.A. — We formed Horizontes Energia S.A., or Horizontes Energia, to generate and trade electricity as an IPP (independent power producer) through the commercial operation of the following of our smaller hydroelectric plants: the Machado Mineiro Small Hydro Plant (SHP), with an installed capacity of 1.72 MW; the Salto do Paraopeba SHP, with an installed capacity of  2.37 MW; the Salto Voltão SHP, with an installed capacity of 8.2 MW; and the Salto do Passo Velho SHP, with an installed capacity of 1.8 MW, as well as other generating projects to be acquired or built with our participation. The concession relating to the Machado Mineiro SHP expires on July 7, 2025; the concessions relating to the other plants expire on October 4, 2030. The Salto do Paraopeba SHP is currently out of service for refurbishment. We expect that this power plant will resume its operations in 2014.

Usina Termelétrica Barreiro S.A. — We formed Usina Termelétrica Barreiro S.A. to participate, in partnership with V&M do Brasil S.A., or Vallourec & Mannesmann, a metallurgic company, in the construction and operation of the 12.9 MW Barreiro Thermoelectric Power Plant, located on Vallourec & Mannesmann’s premises in the Barreiro neighborhood of the city of Belo Horizonte in Minas Gerais.

Cemig PCH S.A. — We formed Cemig PCH S.A. to generate and trade electric energy as an IPP. Its main activity is the production and sale of electricity through the Pai Joaquim SHP, as an IPP. This plant, located on the Araguari River, has an installed capacity of 23 MW.

Hidrelétrica Cachoeirão S.A. — We formed a special-purpose company named Hidrelétrica Cachoeirão S.A., to build and operate the Cachoeirão SHP. This plant, with an installed capacity of 27 MW, is located on the Manhuaçu River, in the eastern part of Minas Gerais. Cemig Generation and Transmission has a 49% ownership interest in Hidrelétrica Cachoeirão S.A. and Santa Maria Energética has a 51% ownership interest.

Paracambi Small Hydroelectric Power Plant — Cemig Generation and Transmission has also negotiated a stake in the construction and operation of the Paracambi Small Hydroelectric Power Plant, in partnership with Light to implement and operate the project. Cemig Generation and Transmission has a 49% interest in this project and Light has a 51% ownership interest. The plant, with an installed capacity of 25 MW, is located on the Lajes River, in the eastern part of  the State of Rio de Janeiro. The concession relating to this plant expires on February, 2031. As of December 31, 2012, we had invested R$203 million in this project.

Baguari Energia S.A .— We operate the Baguari Hydroelectric Power Plant through the Baguari UHE Consortium, in which Baguari Energia has a 49% interest. The power plant has an installed capacity of 140 MW and is located on the Doce River, in the State of Minas Gerais. The energy generated is commercialized in the ACR. Initially, Cemig Generation and Transmission had a 34% interest in this consortium and Furnas Centrais Elétricas S.A. had a 15% interest. On February 2, 2010, Aneel transferred to Baguari Energia the Cemig Generation and Transmission and Furnas Centrais Elétricas S.A joint concession in the Baguari Hydroelectric Power Plant.

Hidrelétrica Pipoca S.A. — Cemig Generation and Transmission has also negotiated a stake in the construction and operation of the Pipoca SHP, in partnership with Omega Energia Renovável S.A., formed by the investment companies “Tarpon Investimentos” and “Warburg Pincus”, to implement and operate the project. Through Cemig Generation and Transmission, we have a 49% interest in

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Hidrelétrica Pipoca S.A. The plant, with an installed capacity of  20 MW, is located on the Manhuaçu River, in the eastern part of the State of Minas Gerais.

Wind Farms

Wind farms are becoming an important means of power generation for the near future. Besides its reduced environmental impact, this energy source is completely renewable and widely available in Brazil, according to recent prospective studies. Also, its fast technical development during recent decades resulted in a lower cost per MWh, compared to other means of power generation. CEMIG is monitoring the accelerated evolution of wind-based power generation and its inclusion in the Brazilian energy portfolio.

Our first wind farm, Morro do Camelinho, began operating in 1994. It is located in Gouveia, a town in northern Minas Gerais. This project is the first wind farm in Brazil to be connected to the national electricity transmission grid. With a total generation capacity of 1 MW, Morro do Camelinho was built through a technical and scientific cooperation agreement with the government of Germany. Taking into account the experimental nature of the facility, and the fact that the equipment used is now obsolescent, Cemig applied to Aneel for permission to de-activate the plant, which was granted on September 2, 2010. On August 15, 2009, Cemig Generation and Transmission’s purchased from Energimp S.A. a 49% interest in three wind farms located in the State of Ceará, for the amount of R$223 million. The three wind farms, named UHE Praia do Morgado, UHE Praias de Parajuru and UHE Volta do Rio, have a total installed capacity of 99.6 MW.

Central Eólica Praias de Parajuru S.A. is located in the city of Beberibe, in the State of Ceará. The commercial operation started in August 2009. All of its generation, totaling 73,525 MWh in 2012, has been sold to Eletrobras, under the Proinfa Program for a period of 20 years.

Central Eólica Praia do Morgado S.A is located in the city of Acaraú, in the State of Ceará. The commercial operation started in May 2010. All its generation, totaling 59.117 MWh in 2012, has been sold to Eletrobrás, under the Proinfa Program for a period of 20 years.

Central Eólica Volta do Rio S.A is located in the city of Acaraú, in the State of Ceará. The commercial operation started in September 2010. All its electricity, totaling 161,238 MWh in 2012, has been sold to Eletrobrás, under the Proinfa Program for a period of 20 years.

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The chart below sets forth the geographic distribution of majority of our generation plants, including subsidiaries and affiliates:

Expansion of Generation Capacity

We are currently involved in the construction of six hydroelectric power plants— Dores de Guanhães, Senhora do Porto, Fortuna II, Jacaré, Santo Antônio and Belo Monte —that will increase the installed generation capacity of our hydroelectric facilities by 1,280 MW   over the next 6 years. The following is a brief description of these projects, the completion of which are subject to various contingencies, certain of which are beyond our control.

SPE Guanhães Energia S.A. — Cemig Generation and Transmission has negotiated an ownership interest in the construction and operation of the Small Hydro Plants, or PCHs, of Dores de Guanhães, Senhora do Porto, Fortuna II and Jacaré. In August 2012, Light Energia acquired from our partner in this project, Investminas Participações S. A., a wholly owned subsidiary of GlobalBank Participações e Investimentos S.A, 100% of its holdings in the company Guanhães Energia S.A, or Guanhães Energia. As a result, Cemig Generation and Transmission has a 49% ownership interest in Guanhães Energia, while Light Energia has the remaining 51%. The purpose of Guanhães Energia is to build and operate these four PCHs, namely: Dores de Guanhães, with 14 MW installed capacity; Senhora do Porto, with 12 MW capacity; Jacaré, with 9 MW; and Fortuna II, with 9 MW. Dores de Guanhães, Senhora do Porto and Jacaré are being built on the Guanhães River, located in the municipality of Dores de Guanhães, State of Minas Gerais, and Fortuna II is being built on the Corrente Grande River, located in the municipalities of Guanhães and Virginópolis, State of Minas Gerais. Construction began in September 2012, and commercial operation is expected to begin in the first half of 2014. The concessions relating to these plants expire in December 2031 with respect to Fortuna II, November 2032 with respect to Dores de Guanhães and October 2032 with respect to Senhora do Porto and Jacaré. As of December 31, 2012, we had invested R$29 million in this project.

Madeira Energia S.A. — MESA is a special-purpose company created to implement, build, operate and maintain the Santo Antônio hydroelectric plant, in the basin of the Madeira River, in the northern region of Brazil. This facility will have a generating capacity of 3,150 MW. The Santo Antônio hydroelectric plant began its operation in March 2012, nine months in advance of the

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original schedule. Cemig Generation and Transmission has a 10% interest in MESA, and based on our ownership interest, we expect to invest R$1,676 million in the development of the project.

Norte Energia S.A. — NESA Since October 2011 Cemig Generation and Transmission owns 74.5% of theAmazônia Energia SPE together with Light Energy, which owns the remaining 25.5%. Amazônia Energia holds 9.77% of a concession to implement, operate and maintain the Belo Monte Hydroelectric Plant, in the Xingu River, in the northern region of Brazil via another SPE, Norte Energia S.A. At the end of 2012 the Belo Monte Hydroelectric Plant was about 20% complete, putting it on schedule for completion in 01/31/2019, an important achievement given the start-up challenges of a 11,233MW hydroelectric power plant, the biggest currently under construction in the world, located in the Amazon Forest. More than 85% of the construction and the equipment required to complete the project have been contracted for, however, the project is still in its initial development phase.  The Brazilian Government Development Bank (Banco Nancional de Desenvolvimento, or “BNDES”) along with two other financing banks loaned R$22.5 billion for the completion of the project, which we believe to be another significant milestone for  the project. Cemig will invest R$ 603 million as equity capital in the project until 2016.

Consortium UHE Itaocara  — In 2008, Cemig Generation and Transmission took part in a consortia (49% of interest) with Itaocara Energia Ltda, a special-purpose owned by Light S.A., created to implement, build, operate and maintain the Itaocara Hydroelectric Power Plant. The plant, with a generating capacity of 151 MW, is located on the Paraíba do Sul River, between the municipalities of Itaocara and Aperibé, in Rio de Janeiro state. Construction is expected to begin in 2013.

Renova Energia S.A.  — Light Energia S.A., which is a subsidiary of Light S.A., holds 32.31% common shares and 21.99% of Renova’s total capital. Renova  is a company generating electricity from renewable sources focused on wind farms and small hydroelectric plants (PCHs). Renova sold a total of 703MW of installed electricity generation capacity in the reserve energy auctions of 2009 and 2010,  the A—3 auction of 2011 and the A-5 auction of 2012. Renova has a current portfolio of 2,051 MW of wind projects and 1,472 of PCHs and other projects in development. Renova is the first and sole company engaged in the generation of alternative electricity trading on the BM&FBovespa. Light’s investment in Renova was R$360 million, which was used for the installation of wind farms.

Co-generation Joint Ventures with Consumers

We intend to enter into joint ventures with industrial consumers to develop co-generation facilities. These facilities would be built on consumers’ premises and would generate electricity using fuel supplied by the consumers’ industrial processes. Each co-generation project would be funded in part through an agreement with the particular consumer to purchase the electricity generated in that consumer’s facility. We would assume the responsibility for operating and maintaining the co-generation facility.

Power Trading

Under the present regulations of the Brazilian electricity sector, power generation companies are allowed to operate in trading as well as the sale of their own production. CEMIG started intensifying this activity in 2009, which is complementary to the sale of its own generation, buying electricity for future sale through its power generation and trading subsidiaries, aiming further to increase the company’s results. CEMIG’s wholesale commercialization policy is approved by the Board of Directors and the transactions are individually approved by the Executive Board.

These transactions were previously submitted for analysis by the Energy Risks Management Committee, in which representatives of various areas of CEMIG — financial, legal, commercial, regulatory and planning — participate, for the purpose of determining the risks and results expected, using, for this, analysis of market conditions, hydrology simulation models, energy risk models, estimates of spot prices and calculation of the profit at risk.

The results of the trading activities depend on market conditions, which may be different from the company’s expectations. To mitigate this risk, CEMIG seeks to avoid carrying positions, selling the electricity bought as soon as possible.

Transmission

Overview

Our transmission business mainly consists of the transfer of electricity from generation power plants to consumer agents directly connected in the basic transmission grid, final consumers and distribution companies. The transmission system is comprised of transmission lines and step-down substations with voltages ranging from 230 kV to 500 kV.

During the year ended December 31, 2012, our transmission businesses recorded revenues totaling R$ 1,680 million. In turn, our usage of the basic transmission grid by connected generation power plants and distribution systems and electricity purchases from

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Itaipu and others suppliers requires us to pay scheduled rates to the  ONS, and owners of different parts of the basic transmission grid. See “-The Brazilian Power Industry” and “Item 5. Operating and Financial Review and Prospects.”

Cemig Generation and Transmission transported 5,468 GWh in 2012 serving 15  high voltage industrial Free Consumers located in the State of Minas Gerais.

The following tables set forth certain operating information pertaining to our transmission capacity for the dates indicated:

	Circuit Length of Transmission Lines in Miles
	As of December 31,
Voltage of Transmission Lines	2012	2011	2010
>525 kV	40	55	38
500 kV	3,042	3,155	2,663
440 kV	135	177	177
345 kV	1,286	1,223	1,347
230 kV	1,343	1,197	909
Total	5,847	5,807	5,134

Transformation Capacity(1)
of Transmission Substations

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