SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549


FORM 6-K

Report of Foreign Private Issuer
Pursuant to Rule 13a-16 or 15d-16 of the
Securities Exchange Act of 1934

For the month of August, 2017

Commission File Number 1-34129


CENTRAIS ELÉTRICAS BRASILEIRAS S.A. - ELETROBRÁS
(Exact name of registrant as specified in its charter)



BRAZILIAN ELECTRIC POWER COMPANY
(Translation of Registrant's name into English)



Avenida Presidente Vargas, 409 - 13th floor,
Edifício Herm. Stoltz - Centro, CEP 20071-003,
Rio de Janeiro, RJ, Brazil
(Address of principal executive office)

Indicate by check mark whether the registrant files or will file annual reports under cover Form 20-F or Form 40-F. 

Form 20-F ___X___ Form 40-F _______

Indicate by check mark whether the registrant by furnishing the information contained in this Form is also thereby furnishing the information to the Commission pursuant to Rule 12g3-2(b) under the Securities Exchange Act of 1934.

Yes _______ No___X____

 
 

 
 

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex I - 2Q17

Financial Information of the Subsidiaries

ASSETS 06/30/2017

Furnas

Chesf

Eletrosul

Eletronorte

Eletropar

Eletronuclear

CGTEE

Amazonas GT

                 

CURRENT

 

 

 

 

 

 

 

 

Cash and Cash Equivalent

52,037

306,379

43,991

42,584

4,241

9,859

13,409

5,453

Accounts Receivable, net

1,265,119

469,396

972,410

1,261,895

-

322,038

72,503

324,314

Financing and Loans

338

32

-

-

-

-

-

-

Marketable Securities

264,838

35,526

387,544

956,710

43,922

95,345

-

36,009

Dividends to Receive (Remuneration of Equity Participations)

71,650

48,666

12,443

-

1,401

-

-

-

Deferred Fiscal Assets (Tax and Contributions)

19,813

13,856

5,838

296,419

691

7,081

2,068

607

Income Tax and Social Contribution

91,254

121,265

15,562

-

2,758

-

-

-

Derivatives

-

-

-

173,255

-

-

-

-

Reimbursement Rights

-

-

-

-

-

-

17,235

-

Guarantees and Linked Deposits

-

15,046

1,992

-

-

-

-

27,670

Inventory

32,145

75,621

34,456

123,776

-

89,770

29,728

21,495

Nuclear Fuel Inventory

-

-

-

-

-

455,737

-

-

Financial Assets

3,322,478

2,220,317

537,612

1,373,308

-

-

-

240,362

Hydrological risk

82,393

-

2,007

12,640

-

-

-

7,066

Others

448,889

341,625

167,099

427,019

735

88,695

7,336

6,694

CURRENT TOTAL

5,650,954

3,647,729

2,180,954

4,667,606

53,748

1,068,525

142,279

669,670

 

 

 

 

 

 

 

 

 

NON-CURRENT

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

LONG-TERM ASSET

-

-

-

-

-

-

-

-

Financial Asset – Itaipu (Parent Company)

-

-

-

-

-

-

-

-

Fuel Consumption Account (Parent Company)

-

-

-

-

-

-

-

-

Dividends to Receive (Equity Participation Remuneration)

-

-

-

-

-

-

-

-

Accounts Receivable, net

273

11,832

-

143,276

-

-

-

-

Financing and Loans - principal

591

-

-

-

-

-

-

-

Marketable Securities

-

945

42

85

-

-

-

-

Diferred Fiscal Assets (Taxes and Contributions)

-

192,757

3,621

34,091

-

-

24,514

-

Income Tax and Social Contribution

-

-

-

602,107

-

-

-

-

Derivatives

-

-

-

145,091

-

-

-

-

Reimbursement Rights

-

-

-

-

-

-

32,713

-

Guarantees and Linked Deposits

854,809

621,014

183,923

469,177

-

95,430

13,568

88,102

Financial Assets

19,582,016

10,827,884

3,050,268

8,643,927

-

791,735

-

74,933

Financial Assets – Indemnitiable Concessions (Generation)

1,227,799

738,282

-

-

-

-

-

-

Advance for equity participation

72,100

479,466

1,006,404

416

-

-

-

-

Hydrological risk

202,865

-

21,576

166,581

-

-

-

-

Others

551,741

152,946

221,502

2,448,292

1,471

567,699

188,859

9,072

LONG-TERM ASSET TOTAL

22,492,194

13,025,126

4,487,336

12,653,043

1,471

1,454,864

259,654

172,107

 

 

 

 

 

 

 

 

 

INVESTIMENTS

6,684,638

5,520,368

2,553,788

4,651,331

163,719

-

-

-

 

 

 

 

 

 

 

 

 

FIXED ASSETS, NET

5,638,213

1,591,164

3,069,750

6,590,870

22

5,068,183

1,095,048

1,869,574

 

 

 

 

 

 

 

 

 

INTANGIBLE ASSET

126,124

57,955

192,717

83,169

23

63,082

2,254

5,357

 

 

 

 

 

 

 

 

 

NON-CURRENT ASSET TOTAL

34,941,169

20,194,613

10,303,591

23,978,413

165,235

6,586,129

1,356,956

2,047,038

 

 

 

 

 

 

 

 

 

TOTAL ASSETS

40,592,123

23,842,342

12,484,545

28,646,019

218,983

7,654,654

1,499,235

2,716,708

 

1

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex I - 2Q17

Financial Information of the Subsidiaries

ASSET 06/30/2017

ED Alagoas

ED Rondônia

ED Piauí

ED Acre

ED Roraima

Amazonas D

 

 

 

 

 

 

 

CURRENT

 

 

 

 

 

 

Cash and Cash Equivalents

72,667

37,526

6,542

18,437

6,755

80,098

Accounts Receivable, net

337,307

230,278

349,472

85,456

82,895

656,331

Financing and Loans

-

-

-

-

-

-

Marketable Securities

3,007

52,580

17,521

-

-

237,988

Dividends to Receive (Equity Participations Remuneration)

-

-

-

-

-

-

Deferred Fiscal Asset (Taxes and Contributions)

12,962

33,364

16,352

7,650

6,095

2,318

Income Tax and Social Contribution

-

-

-

602

-

-

Derivatives

-

-

-

-

-

-

Reimbursement Rights

27,305

256,224

23,016

55,524

81,150

227,666

Guarantees and Linked Deposits

-

-

-

483

-

9,361

Inventory

9,737

16,211

15,337

2,313

16,048

115,001

Amounts to Receive 12,783/13 Law

-

-

-

-

-

-

Regulatory Asset (Installment A - CVA)

55,422

40,371

153,350

60,641

14,853

37,202

Financial Assets

-

-

-

-

-

-

Others

39,066

52,647

69,920

71,650

14,915

131,782

CURRENT TOTAL

557,473

719,201

651,510

302,756

222,711

1,497,747

 

 

 

 

 

 

 

NON-CURRENT

 

 

 

 

 

 

 

 

 

 

 

 

 

LONG-TERM ASSET

 

 

 

 

 

 

Dividends to Receive (Equity Participations Remuneration)

-

-

-

-

-

-

Accounts Receivable, net

307,947

16,677

225,652

44,679

8,851

97,988

Financing and Loans - principal

-

-

-

-

-

-

Marketable Securities

-

-

-

-

-

-

Deferred Fiscal Assets (Taxes and Contributions)

4,477

5,850

7,668

1,768

9,562

1,469,858

Income Tax and Social Contribution

-

-

-

-

-

-

Derivatives

-

-

-

-

-

-

Reimbursement Rights

-

3,591,069

-

240,643

197,210

3,827,883

Guarantees and Linked Deposits

73,960

135,089

17,124

10,552

29,915

448,734

Amounts to Receive - Law 12,783/13

-

-

-

-

-

-

Financial Assets

-

-

-

-

-

-

Financial Asset – Indemnitiable Concession (Distribution)

885,014

1,165,919

923,040

430,497

202,982

2,137,373

Advance for Equity Participations

-

-

-

-

-

-

Regulatory Asset (Installment A - CVA)

47,766

-

-

-

-

-

Others

564

2,447

1,547

-

4,257

12

LONG-TERM ASSET TOTAL

1,319,728

4,917,051

1,175,031

728,139

452,777

7,981,848

 

 

 

 

 

 

 

INVESTIMENTS

168

1,806

146

-

-

17,107

 

 

 

 

 

 

 

FIXED ASSETS, NET

30,536

27,916

38,034

8,865

15,311

1,209,109

 

 

 

 

 

 

 

INTANGIBLE

-

34,161

19,344

20,294

4,520

131,263

 

 

 

 

 

 

 

TOTAL NON-CURRENT ASSETS

1,350,432

4,980,934

1,232,555

757,298

472,608

9,339,327

 

 

 

 

 

 

 

TOTAL ASSETS

1,907,905

5,700,135

1,884,065

1,060,054

695,319

10,837,074

 

2

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex I - 2Q17

Financial Information of the Subsidiaries

ASSETS 06/30/2016

Furnas

Chesf

Eletrosul

Eletronorte

Eletropar

Eletronuclear

CGTEE

Amazonas GT

                 

CURRENT

 

 

 

 

 

 

 

 

Cash and Cash Equivalent

19,176

148,800

26,138

18,534

2,537

1,786

17,468

40,490

Accounts Receivable, net

590,338

358,931

192,503

1,279,682

-

212,731

236,937

647,316

Financing and Loans

1,041

2,419

1,492

-

-

-

-

-

Marketable Securities

924,033

6,501

144,879

509,030

49,875

108,157

-

220,374

Dividends to Receive (Remuneration of Equity Participations)

72,015

36,103

5,556

-

964

-

-

-

Deferred Fiscal Assets (Tax and Contributions)

22,184

12,451

5,055

206,027

3,387

17,415

10,369

5,992

Income Tax and Social Contribution

205,964

74,865

17,447

-

-

-

-

-

Derivatives

-

-

-

72,602

-

-

-

-

Reimbursement Rights

-

-

-

-

-

-

16,360

-

Guarantees and Linked Deposits

-

69,800

42,526

-

-

-

-

-

Inventory

33,547

78,887

37,738

108,931

-

124,753

34,679

32,730

Amounts to Receive - 12,783/2013 Law

-

-

-

-

-

-

-

-

Nuclear Fuel inventory

-

-

-

-

-

402,453

-

-

Financial Assets

-

128,281

54,744

304,117

-

-

-

-

Hydrological risk

111,380

-

2,007

34,313

-

-

-

11,414

Others

1,979,678

917,038

530,085

2,533,236

56,763

867,295

315,813

958,316

CURRENT TOTAL

2,378,862

1,270,924

758,334

2,818,216

60,531

949,756

322,903

973,285

 

 

 

 

 

 

 

 

 

NON-CURRENT

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

LONG-TERM ASSET

 

 

 

 

 

 

 

 

Financial Asset – Itaipu (Parent Company)

-

-

-

-

-

-

-

-

Fuel Consumption Account (Parent Company)

-

-

-

-

-

-

-

-

Dividends to Receive (Equity Participation Remuneration)

-

-

-

-

-

-

-

-

Clients (Consumers and Resellers)

537,842

2,630

695,773

3,485

-

-

-

-

Financing and Loans - principal

929

-

2,126

-

-

-

-

-

Marketable Securities

-

1,607

42

250

-

-

-

-

Diferred Fiscal Asset (Taxes and Contributions)

-

181,773

4,275

38,568

3,416

-

33,659

-

Income Tax and Social Contribution

-

-

-

288,528

-

-

-

-

Derivatives

-

-

-

68,936

-

-

-

-

Reimbursement Rights

-

-

-

-

-

-

-

-

Linked Deposits

763,209

1,170,665

153,512

508,498

55

61,720

5,272

67,887

Financial Asset

19,844,738

13,290,708

3,280,485

8,961,897

-

736,121

-

-

Financial Asset – Indemnitiable Concessions (Generation)

1,213,707

716,002

-

-

-

-

-

-

Advance for equity participation

67,517

396,365

927,940

109,188

-

-

-

-

Hydrological risk

270,409

-

23,583

210,119

-

-

-

7,713

Others

215,348

199,641

106,097

2,348,195

1,384

474,645

158,330

9,070

LONG-TERM ASSET TOTAL

22,913,699

15,959,391

5,193,833

12,537,664

4,855

1,272,486

197,261

84,670

 

 

 

 

 

 

 

 

 

INVESTIMENTS

6,647,912

4,671,994

2,115,959

4,499,560

111,361

-

-

-

 

 

 

 

 

 

 

 

 

FIXED ASSETS, NET

5,778,388

1,667,155

3,239,276

6,899,197

29

5,183,984

1,398,881

1,890,046

 

 

 

 

 

 

 

 

 

INTANGIBLE ASSET

115,091

62,132

216,263

160,852

23

57,203

2,535

5,357

 

 

 

 

 

 

 

 

 

NON-CURRENT ASSET TOTAL

35,455,090

22,360,672

10,765,331

24,097,273

116,268

6,513,673

1,598,677

1,980,073

 

 

 

 

 

 

 

 

 

TOTAL ASSETS

37,833,952

23,631,596

11,523,665

26,915,489

176,799

7,463,429

1,921,580

2,953,358

 

3

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex I - 2Q17

Financial Information of the Subsidiaries

 

ASSETS 06/30/2016

ED Alagoas

ED Rondônia

ED Piauí

ED Acre

ED Roraima

Amazonas Energia

 

 

 

 

 

 

 

CURRENT

 

 

 

 

 

 

Cash and Cash Equivalents

20,215.00

20,140.00

3,685.00

7,814.00

6,517.00

33,605.00

Accounts Receivable, net

320,158.00

241,579.00

341,757.00

95,031.00

39,608.00

629,394.00

Loans and Financing

-

-

-

-

-

-

Marketable Securities

14,669.00

165,401.00

147.00

-

-

12,465.00

Dividends to Receive (Remuneration of Equity Participation)

-

-

-

-

-

-

Deferred Fiscal Asset (Taxes and Contributions)

10,707.00

17,845.00

21,103.00

6,892.00

5,011.00

2,144.00

Income Tax and Social Contribution

-

-

-

882.00

-

-

Derivatives

-

-

-

-

-

-

Reimbursement Rights

44,988.00

164,646.00

92,564.00

135,308.00

76,820.00

875,033.00

Guarantees and Linked Deposits

-

-

-

475.00

-

-

Inventory

7,445.00

14,272.00

13,347.00

1,434.00

2,859.00

103,411.00

Amounts to Receive 12,783/13 Law

-

-

-

-

-

-

Regulatory Asset (Installment A – CVA)

106,870.00

127,618.00

69,466.00

57,278.00

1,517.00

73,831.00

Financial Assets

-

-

-

-

-

-

Others

42,880.00

75,483.00

47,796.00

32,073.00

6,860.00

640,534.00

CURRENT TOTAL

567,932.00

826,984.00

589,865.00

337,187.00

139,192.00

2,370,417.00

 

 

 

 

 

 

 

NON-CURRENT

 

 

 

 

 

 

 

 

 

 

 

 

 

LONG-TERM CURRENT

 

 

 

 

 

 

Dividends to Receive (Equity Participation Remuneration)

-

-

-

-

-

-

Accounts Receivable, net

207,731.00

18,083.00

216,671.00

27,301.00

9,693.00

66,557.00

Loans and Financing - principal

-

-

-

-

-

-

Marketable Securities

-

-

-

-

-

-

Deferred Fiscal Asset (Taxes and Contributions)

4,623.00

7,162.00

5,580.00

1,720.00

8,248.00

2,450,287.00

Income Tax and Social Contribution

-

-

-

-

-

-

Derivatives

-

-

-

-

-

-

Reimbursement Rights

-

3,379,492.00

-

243,373.00

204,050.00

6,487,937.00

Guarantees and Linked Deposits

45,631.00

116,732.00

15,691.00

7,356.00

19,483.00

344,732.00

Amounts to Receive - 12,783/2013 Law

-

-

-

-

-

-

Financial Asset

-

-

-

-

-

-

Financial Asset – Indemnitiable Concessions (D)

796,841.00

1,050,359.00

725,662.00

343,398.00

193,157.00

1,410,427.00

Advance for equity participation

-

-

-

-

-

-

Regulatory Asset (Installment A - CVA)

51,583.00

-

-

-

-

-

Others

564.00

2,447.00

1,325.00

-

2,180.00

637,355.00

LONG-TERM CURRENT TOTAL

1,106,973.00

4,574,275.00

964,929.00

623,148.00

436,811.00

11,397,295.00

 

 

 

 

 

 

 

INVESTIMENTS

168.00

1,806.00

146.00

-

-

12,929.00

 

 

 

 

 

 

 

FIXED ASSETS, NET

30,144.00

28,014.00

32,395.00

8,983.00

19,741.00

1,244,597.00

 

 

 

 

 

 

 

INTANGIBLE

35,763.00

39,908.00

11,695.00

33,329.00

6,046.00

167,774.00

 

 

 

 

 

 

 

TOTAL NON-CURRENT ASSETS

1,173,048.00

4,644,003.00

1,009,165.00

665,460.00

462,598.00

12,822,595.00

 

 

 

 

 

 

 

TOTAL ASSETS

1,740,980

5,470,987

1,599,030

1,002,647

601,790

15,193,012

 

4

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex I - 2Q17

Financial Information of the Subsidiaries

LIABILITIES 06/30/2017

Furnas

Chesf

Eletrosul

Eletronorte

Eletropar

Eletronuclear

CGTEE

Amazonas GT

 

 

 

 

 

 

 

 

 

CURRENT

 

 

 

 

 

 

 

 

Accounts payable

333,681

270,039

114,257

529,719

-

727,348

94,036

202,151

Loans and Financing - principal

1,823,337

989,762

694,651

971,133

-

375,532

535,316

668,747

Loans and Financing - charges

139,006

5,880

124,505

54,308

-

23,096

119,028

149

Bonds

-

18,807

-

15,097

-

-

-

-

Tax and Social Contributions

260,985

96,595

29,934

89,813

94

46,911

35,463

177,843

Income Tax and Social Contribution

32,041

18,938

167

-

32

-

-

16,406

Derivatives

-

-

-

555

-

-

-

-

Reimbursement Obligations

-

-

-

-

-

-

-

-

Advance to clients (Early Energy Sale)

-

-

-

326,913

-

-

-

-

Shareholders' Remuneration (dividends to pay)

317,007

-

97,477

736

-

-

90,263

-

Estimated Obligations

227,989

364,057

119,923

421,069

348

166,411

53,888

28,961

Provisions for Contingencies

-

-

-

-

300

-

401,083

-

Post-Employment Benefit (Complementary Pension Fund)

9,405

180,000

8,119

-

-

2,977

-

-

Leasing

-

-

-

-

-

-

-

-

Provisions for Onerous Contracts

-

-

-

14,245

-

-

-

-

Concessions to Pay - UBP

948

-

2,485

-

-

-

-

-

Regulatory fees

12,499

66,461

44,125

347,166

-

23,246

25,718

8,253

Others

732,869

334,753

286,314

773,063

1,943

276,031

38,591

38,641

CURRENT TOTAL

3,889,767

2,345,292

1,521,957

3,543,817

2,717

1,641,552

1,393,386

1,141,151

 

 

 

 

 

 

 

 

 

NON-CURRENT

 

 

 

 

 

 

 

 

Shareholders Remuneration (dividends to pay)

-

-

-

-

-

-

-

-

Accounts payable

-

-

-

82,748

-

-

16,555

-

Loans and Financing - principal

8,713,460

1,135,755

3,951,585

4,252,610

-

7,656,624

2,206,501

1,133,954

Bonds

-

140,167

-

187,852

-

-

-

-

Tax and Social Contributions

457,591

19,262

-

26,231

-

15,345

-

-

Income Tax and Social Contribution

5,170,474

3,293,277

436,865

-

16,137

-

-

65,790

Derivatives

-

-

-

64,142

-

-

-

-

Reimbursement Obligations

-

-

-

-

-

-

-

-

Advance to clients (Early Energy Sale)

-

-

-

558,475

-

-

-

-

Estimated Obligations

31,419

100,135

20,815

28,100

-

78,242

6,569

-

Provisions for Contingencies

824,502

1,953,771

144,189

848,859

-

225,482

-

60,726

Provision for uncovered liability in invested company

-

-

219,112

-

-

-

-

- 225,357

Post-Employment Benefit (Complementary Pension Fund)

144,759

1,183,970

268,634

16,303

-

46,002

71,699

477

Leasing

-

-

-

-

-

-

-

-

Provision for Onerous Contracts

460,147

279,907

-

376,700

-

865,600

-

-

Concessions to Pay - UBP

35,528

-

28,174

-

-

-

-

-

Sector Charges (statutory tax)

296,967

407,959

-

-

-

-

-

-

Obligations for asset demobilization (Nuclear Power Plants)

-

-

-

-

-

1,444,067

-

-

Advance for future capital Increase

52,748

-

3

-

-

-

663,191

-

Others

139,316

19,454

39,473

2,542,551

1,442

-

-

539,967

NON-CURRENT TOTAL

16,326,911

8,533,657

5,108,850

8,984,571

17,579

10,331,362

2,964,515

1,575,557

 

 

 

 

 

 

 

 

 

SHAREHOLDERS’ EQUITY

 

 

 

 

 

 

 

 

Share Capital

6,531,154

9,753,953

4,359,226

11,576,263

118,054

6,607,258

845,510

-

Capital reserves

5,053,045

4,916,199

-

-

-

-

-

-

Profit Reserves

9,168,995

-

1,365,128

3,933,602

27,652

-

2,596

-

Additional Dividend Purposed

-

-

-

-

-

-

-

-

Profit/Losses Accumulated

1,151,991

102,918

298,934

630,382

5,253

- 10,763,300

- 3,596,462

-

Others Comprehensive Income

- 1,528,740

- 1,825,668

- 184,828

- 22,616

47,728

- 162,218

- 110,310

-

Minority shareholdings

- 1,000

15,991

15,278

-

-

-

-

-

 

 

 

 

 

 

 

 

 

TOTAL SHAREHOLDERS’ EQUITY

20,375,445

12,963,393

5,853,738

16,117,631

198,687

- 4,318,260

- 2,858,666

-

 

 

 

 

 

 

 

 

 

TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY

40,592,123

23,842,342

12,484,545

28,646,019

218,983

7,654,654

1,499,235

2,716,708

 

5

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex I - 2Q17

Financial Information of the Subsidiaries

LIABILITIES 06/30/2017

ED Alagoas

ED Rondonia

ED Piauí

ED Acre

ED Roraima

Amazonas

 

 

 

 

 

 

 

CURRENT

 

 

 

 

 

 

Accounts payable

142,001

1,766,511

134,079

227,499

584,491

5,317,607

Financig and Loans - principal

248,236

147,518

434,602

66,119

5,607

150,407

Financig and Loans - charges

-

44

94,713

-

-

264

Bonds

-

-

-

-

-

-

Taxes and Social Contributions

78,931

63,609

162,433

41,183

22,941

42,642

Income Tax and Social Contribution

250

-

-

-

-

5,664

Derivatives

-

-

-

-

-

-

Reimbursement Obligations

38,764

13,203

-

-

16,969

-

Advance to clients (Early Sell of Energy)

-

-

-

-

-

-

Shareholders' Remuneration (dividends to pay)

-

-

-

-

-

-

Estimated Obligations

23,043

25,786

34,829

8,913

18,264

58,663

Provisions for Contingencies

-

-

-

-

-

-

Post-Employment Benefit (Complementary Pension Fund)

914

4,620

-

361

-

-

Leasing

-

-

-

-

-

136,907

Provisions for Onerous Contracts

7,808

102,958

32,691

-

7,765

378,899

Regulatory fees

27,809

26,444

23,288

42,228

-

70,798

Regulatory Liability (Installment A – CVA)

31,912

62,255

70,789

32,303

4,096

115,906

Others

23,670

27,122

49,580

22,813

15,270

69,447

CURRENT TOTAL

623,338

2,240,070

1,037,004

441,419

675,403

6,347,204

 

 

 

 

 

 

 

NON-CURRENT

 

 

 

 

 

 

Accounts payable

-

1,174,697

-

271,432

282,242

7,921,898

Financig and Loans - principal

1,504,984

1,031,665

1,548,069

373,815

175,371

2,432,864

Bonds

-

-

-

-

-

-

Taxes and Contributions

64,933

15,752

58,430

82,976

-

-

Income Tax and Social Contribution

-

-

-

-

-

-

Derivatives

-

-

-

-

-

-

Reimbursement Obligations

-

151,353

-

81,609

60,030

1,157,262

Advance to clients (Early Sell of Energy)

-

-

-

-

-

-

Estimated Obligations

1,939

-

3,273

95

183

835

Provisions for Contingencies

125,725

220,745

142,231

146,491

56,933

1,688,628

Provision for uncovered liabilities on invested comapnies

-

-

-

-

-

225,357

Post-Employment Benefit (Complementary Pension Fund)

39,280

-

-

-

1,633

1,325

Leasing

-

-

-

-

-

987,943

Provision for Onerous Contracts

-

-

-

-

-

-

Concessions to Pay - UBP

-

-

-

-

-

-

Sector Charges (Statutory Taxes)

24,135

55,548

55,900

-

-

-

Advance for future capital Increase

159,155

-

308,978

69,462

80,089

117,446

Regulatory Liability (Installment A – CVA)

25,976

-

-

-

-

-

Others

34,273

2,409,529

503

126

73,529

59,656

NON-CURRENT TOTAL

1,980,400

5,059,289

2,117,384

1,026,006

730,010

14,593,214

 

 

 

 

 

 

 

SHAREHOLDERS’ EQUITY

 

 

 

 

 

 

Social Capital

734754

1325369

1272747

475789

684204

4610171

Capital Reserves

0

0

0

0

0

0

Profit Reserves

0

0

0

0

0

0

Additional Dividend Purposes

0

0

0

0

0

0

Accumulated Profit/Losses

-1374896

-2920469

-2521877

-882755

-1391310

-14707873

Other Comprehensive Income

-55691

-4124

-21193

-405

-2988

-5642

Minority shareholdings

0

0

0

0

0

0

 

 

 

 

 

 

 

TOTAL SHAREHOLDERS’ EQUITY

(695,833)

(1,599,224)

(1,270,323)

(407,371)

(710,094)

(10,103,344)

 

 

 

 

 

 

 

LIABILITIES AND SHAREHOLDERS’ EQUITY TOTAL

1,907,905

5,700,135

1,884,065

1,060,054

695,319

10,837,074

 

6

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex I - 2Q17

Financial Information of the Subsidiaries

LIABILITIES 06/30/2016

Furnas

Chesf

Eletrosul

Eletronorte

Eletropar

Eletronuclear

CGTEE

Amazonas GT

 

 

 

 

 

 

 

 

 

CURRENT

 

 

 

 

 

 

 

 

Accounts payable

425,032

393,890

96,765

547,984

-

580,200

191,963

186,417

Loans and Financing - principal

976,870

341,292

753,072

635,432

-

324,502

333,291

1,076,469

Loans and Financing - charges

257,329

12,990

65,086

33,508

-

21,548

12,492

23,425

Bonds

-

-

-

13,650

-

-

-

-

Tax and Social Contributions

249,803

89,860

67,892

222,705

72

62,878

14,081

84,092

Income Tax and Social Contribution

24,986

32,314

43

207,755

413

-

-

9,114

Derivatives

-

-

-

113

-

-

-

-

Reimbursement Obligations

-

-

-

-

-

-

-

-

Advance to clients (Early Energy Sale)

-

-

-

60,504

-

-

-

-

Shareholders Remuneration (dividends to pay)

-

-

41,875

86,789

-

-

79,970

-

Estimated Obligations

187,947

212,225

74,655

194,055

316

102,205

12,052

19,127

Provisions for Contingencies

-

28,118

-

-

300

-

51,646

-

Post-Employment Benefit (Complementary Pension Fund)

8,659

27,081

7,415

-

-

2,730

-

-

Leasing

-

-

-

-

-

-

-

-

Provisions for Onerous Contracts

-

-

-

9,073

-

-

-

-

Concessions to Pay - UBP

923

-

2,417

-

-

-

-

-

Regulatory fees

109,610

123,378

44,571

295,816

-

5,626

1,305

9,780

Others

373,318

124,580

216,440

1,261,079

3,930

258,152

31,373

583,481

CURRENT TOTAL

2,614,477

1,385,728

1,370,231

3,568,463

5,031

1,357,841

728,173

1,991,905

 

 

 

 

 

 

 

 

 

NON-CURRENT

 

 

 

 

 

 

 

 

Shareholders Remuneration (dividends to pay)

-

-

-

-

-

-

-

-

Accounts payable

-

-

-

253,166

-

-

18,920

-

Loans and Financing - principal

9,342,778

1,047,823

3,616,189

4,332,327

-

7,241,695

2,229,888

429,127

Bonds

-

-

-

188,581

-

-

-

-

Tax and Social Contributions

548,551

20,777

17,587

-

-

-

-

-

Income Tax and Social Contribution

4,512,900

2,996,148

391,535

-

15,976

-

-

-

Derivatives

-

-

-

53,743

-

-

-

-

Reimbursement Obligations

-

-

-

-

-

-

-

-

Advance to clients (Early Energy Sale)

-

-

-

623,456

-

-

-

-

Estimated Obligations

46,022

51,948

5,166

11,219

-

52,657

1,262

-

Provisions for Contingencies

840,524

1,770,378

90,871

899,631

-

198,129

-

55,570

Provision for uncovered liability in invested company

-

-

261,137

-

-

-

-

-

Post-Employment Benefit (Complementary Pension Fund)

182,247

1,234,673

185,382

25,591

-

49,048

7,112

95

Leasing

-

-

-

-

-

-

-

-

Provision for Onerous Contracts

868,224

225,428

-

239,382

-

1,677,269

-

-

Concessions to Pay - UBP

36,131

-

25,126

-

-

-

-

-

Sector Charges (statutory tax)

130,963

278,623

-

-

-

-

4,333

-

Obligations for asset demobilization (Nuclear Power Plants)

-

-

-

-

-

1,242,516

-

-

Advance for future capital Increase

46,587

-

3

-

-

-

455,409

-

Others

2

101,229

108,230

2,133,783

1,356

21,108

-

520,336

NON-CURRENT TOTAL

16,554,929

7,727,027

4,701,226

8,760,879

17,332

10,482,422

2,716,924

1,005,128

 

 

 

 

 

 

 

 

 

SHAREHOLDERS’ EQUITY

 

 

 

 

 

 

 

 

Social Capital

6,531,154

9,753,953

4,359,226

11,576,263

118,054

6,607,258

845,510

-

Capital Reserves

5,053,045

4,916,199

-

-

-

-

-

-

Profit Reserves

-

-

305,500

354,075

481

-

2,596

-

Additional Dividend Purposes

-

-

-

-

-

-

-

-

Accumulated Profit/Losses

8,470,346

1,484,606

903,225

2,681,955

3,711

- 10,902,889

- 2,330,597

- 43,675

Other Comprehensive Income

- 1,391,023

- 1,651,843

- 129,475

- 26,146

32,190

- 81,203

- 41,026

-

Minority shareholdings

1,024

15,926

13,732

-

-

-

-

-

 

 

 

 

 

 

 

 

 

TOTAL SHAREHOLDERS’ EQUITY

18,664,546

14,518,841

5,452,208

14,586,147

154,436

- 4,376,834

- 1,523,517

- 43,675

 

 

 

 

 

 

 

 

 

LIABILITIES AND STOCKHOLDERS’ EQUITY TOTAL

37,833,952

23,631,596

11,523,665

26,915,489

176,799

7,463,429

1,921,580

2,953,358

 

7

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex I - 2Q17

Financial Information of the Subsidiaries

LIABILITIES 06/30/2016

ED Alagoas

ED Rondônia

ED Piauí

ED Acre

ED Roraima

Amazonas

 

 

 

 

 

 

 

CURRENT

 

 

 

 

 

 

Accounts payable

255,207

1,253,342

393,649

303,161

611,964

7,113,078

Financig and Loans - principal

350,369

152,548

647,118

111,384

18,142

231,762

Financig and Loans - charges

-

-

49,607

1,803

-

2,235

Bonds

-

-

-

-

-

-

Taxes and Social Contributions

79,388

67,925

203,423

45,700

14,334

83,487

Income Tax and Social Contribution

269

-

-

-

-

573

Derivatives

-

-

-

-

-

-

Reimbursement Obligations

62,229

205,741

-

6,630

-

-

Advance to clients (Early Sell of Energy)

-

-

-

-

-

-

Shareholders Remuneration (dividends to pay)

-

-

-

-

-

-

Estimated Obligations

19,432

19,002

39,852

5,758

19,989

52,930

Provisions for Contingencies

-

-

-

-

-

-

Post-Employment Benefit (Complementary Pension Fund)

2,781

790

39,209

-

-

-

Leasing

-

-

-

-

-

135,914

Provisions for Onerous Contracts

-

-

-

-

-

-

Regulatory fees

22,373

26,137

26,743

36,755

-

-

Regulatory Asset (Installment A – CVA)

47,149

90,077

50,673

23,965

-

46,389

Others

23,161

41,881

64,319

24,366

17,594

116,165

CURRENT TOTAL

862,358

1,857,443

1,514,593

559,522

682,023

7,782,533

 

 

 

 

 

 

 

NON-CURRENT

 

 

 

 

 

 

Accounts payable

-

1,099,575

-

249,971

141,310

7,861,211

Financig and Loans - principal

901,763

615,429

691,852

193,764

40,788

1,161,931

Bonds

-

-

-

-

-

-

Taxes and Contributions

91,513

4,209

201,269

76,327

-

-

Income Tax and Social Contribution

-

-

-

-

-

-

Derivatives

-

-

-

-

-

-

Reimbursement Obligations

-

149,649

-

143,850

57,059

2,216,969

Advance to clients (Early Sell of Energy)

-

-

-

-

-

-

Estimated Obligations

1,934

-

2,067

20

206

644

Provisions for Contingencies

106,510

150,453

79,418

11,425

46,705

537,487

Provision for uncovered liabilities on invested comapnies

-

-

-

-

-

43,675

Post-Employment Benefit (Complementary Pension Fund)

30,571

-

7,103

-

437

277

Leasing

-

-

-

-

-

1,075,986

Provision for Onerous Contracts

-

-

-

-

-

-

Concessions to Pay - UBP

-

-

-

-

-

-

Sector Charges (Statutory Taxes)

27,161

44,575

43,798

-

-

-

Advance for future capital Increase

-

-

-

12,787

-

-

Regulatory Liability (Installment A – CVA)

33,733

-

-

-

-

-

Others

32,918

2,135,849

502

197

119,933

180,799

NON-CURRENT TOTAL

1,226,103

4,199,739

1,026,009

688,341

406,438

13,078,979

 

 

 

 

 

 

 

SHAREHOLDERS’ EQUITY

 

 

 

 

 

 

Social Capital

734,754.00

1,325,369.00

1,272,747.00

475,789.00

684,204.00

4,610,171.00

Capital Reserves

-

-

-

-

-

-

Profit Reserves

-

-

-

-

-

-

Additional Dividend Purposes

-

-

-

-

-

-

Accumulated Profit/Losses

- 1,039,427.00

- 1,911,777.00

- 2,206,953.00

- 720,765.00

- 1,169,569.00

- 10,276,250.00

Other Comprehensive Income

- 42,808.00

213.00

- 7,366.00

- 240.00

- 1,306.00

- 2,421.00

Minority shareholdings

-

-

-

-

-

-

 

 

 

 

 

 

 

TOTAL SHAREHOLDERS’ EQUITY

(347,481)

(586,195)

(941,572)

(245,216)

(486,671)

(5,668,500)

 

 

 

 

 

 

 

LIABILITIES AND SHAREHOLDERS’ EQUITY TOTAL

1,740,980

5,470,987

1,599,030

1,002,647

601,790

15,193,012

 

8

 
 

 

DFR - Investor Relations Superintendence
Marketletter - Annex I - 2Q17
Financial Information of the Subsidiaries

STATEMENT OF INCOME 06/30/2017

Furnas

Chesf

Eletrosul

Eletronorte

Eletropar

Eletronuclear

CGTEE

Amazonas GT

 

 

 

 

 

 

 

 

 

Operational Revenues

4,659,245

2,533,548

999,485

2,747,391

-

1,390,041

202,175

338,858

 

 

 

 

 

 

 

 

 

Electric Energy Supply (sell) - Generation

2,029,140

59,619

414,443

1,057,619

-

1,584,962

225,800

255,509

Electric Energy Supply - Generation

96,135

430,874

9,782

644,215

-

-

-

-

Short Term Electric Energy - Generation

40,231

180,316

11,346

532,604

-

-

-

-

Renewed Plants Operation and Maintenance Revenue - Generation

423,430

660,644

-

8,159

-

-

-

-

Construction Plants Revenue - Generation

7,865

12,299

-

-

-

-

-

-

Financial – Return on Investment - Generation

-

29,757

-

-

-

-

-

-

Renewed Lines Operation and Maintenance Revenue - Transmission

633,098

497,548

307,498

234,537

-

-

-

-

Operation and Maintenance Revenue - Transmission

19,438

41,844

58,648

7,965

-

-

-

-

Construction Revenue - Transmission

99,343

218,777

35,929

28,320

-

-

-

-

Financial – Return on Investment - Transmission

1,735,487

741,248

249,688

561,108

-

-

-

193,499

Others Operational Revenues

80,890

22,070

22,985

180,162

-

-

879

-

 

 

 

 

 

 

 

 

 

Deductions to Operational Revenues

- 505,812

- 361,448

- 110,834

- 507,298

-

- 194,921

- 24,504

- 110,150

 

 

 

 

 

 

 

 

 

Operational Expenses

- 2,313,021

- 1,837,660

- 373,052

- 1,918,853

- 3,005

- 1,079,317

(435,177)

(199,466)

 

 

 

 

 

 

 

 

 

Personnel, Supplies and Services

- 1,224,423

- 854,977

- 309,970

- 929,151

- 2,068

- 498,720

- 167,099

- 78,906

Energy Purchased for Resale

- 386,839

- 133,898

- 121,428

- 83,284

-

-

- 105,138

- 41,166

Charges upon use of eletricity network

- 259,831

- 324,350

- 13,505

- 276,554

-

- 49,501

- 23,471

- 12,026

Construction

- 107,208

- 231,076

- 35,929

- 28,320

-

-

-

-

Electric Energy production cost

- 211,792

-

-

-

-

- 204,820

- 18,341

141,416

Donations and Contributions

- 22,479

- 7,015

-

- 1,023

-

-

-

-

Depreciation and Amortization

- 129,783

- 49,206

- 90,034

- 225,222

- 12

- 198,067

- 31,840

- 31,317

Operating Provisions

230,174

- 161,188

215,879

- 252,264

-

- 75,703

- 74,719

- 904

Others

- 200,840

- 75,950

- 18,065

- 123,035

- 925

- 52,506

- 14,569

- 176,563

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

OPERATING RESULT BEFORE FINANCIAL RESULT

2,346,224

695,888

626,433

828,538

(3,005)

310,724

(233,002)

139,392

 

 

 

 

 

 

 

 

 

FINANCIAL REVENUES (EXPENSES)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Revenue from financial investments

21,760

17,663

25,839

42,561

3,247

2,713

2,665

1,559

Interest, Commission and Rates revenue (loans and financing)

33,146

-

-

-

-

-

-

-

Moratorium Increase on electric energy

7,603

10,357

-

41,674

-

-

-

-

Net Monetary Updates

10,690

10,421

- 10,342

145,028

-

4,647

-

6,201

Net Exchange Updates

606

-

9,723

942

-

12,298

23

-

Derivatives

-

-

-

96,465

-

-

-

-

Others Financial Revenues

20,758

30,143

52,872

1,834

287

36,977

681

6,348

Debt Charges - financing and loans

- 536,696

- 141,236

- 255,704

- 305,274

-

- 41,442

- 270,803

- 133,650

Debt Charges - accounts payable

-

-

- 4,156

-

-

-

-

-

Charges – shareholders remuneration

-

-

- 5,077

-

-

-

- 4,831

-

Passive monetary variation

- 65,149

8,629

- 18,329

- 97,213

-

- 4,638

-

- 11,950

Passive exchange variation

- 9,040

-

- 29,627

- 2,665

-

- 25,662

-

-

Losses on derivatives

-

-

-

- 27,573

-

-

-

-

Others Financial Expenses

- 111,371

- 58,662

- 14,812

- 93,199

- 345

- 55,656

- 278

- 9,431

 

 

 

 

 

 

 

 

 

FINANCIAL RESULT

(627,693)

(122,685)

(249,613)

(197,420)

3,189

(70,763)

(272,543)

(140,923)

 

 

 

 

 

 

 

 

 

EQUITY PARTICIPATION RESULT

43,487

46,229

48,360

80,275

5,102

-

-

-

 

 

 

 

 

 

 

 

 

RESULT BEFORE SOCIAL CONTRIBUTION, INCOME TAX, EMPLOYEES AND MANAGEMENT PARTICIPATION AND MINORITY PARTICIPATION

1,762,018

619,432

425,180

711,393

5,286

239,961

(505,545)

(1,531)

 

 

 

 

 

 

 

 

 

Income Tax and Social Contribution and Fiscal Incentives Revenue

- 594,639

- 249,106

- 124,231

- 95,843

- 32

- 50,398

-

- 65,790

 

 

 

 

 

 

 

 

 

RESULT BEFORE EQUITY PARTICIPATIONS

1,167,379

370,326

300,949

615,550

5,254

189,563

(505,545)

(67,321)

 

 

 

 

 

 

 

 

 

Minority Participation

15,388

-

- 2,015

-

-

-

-

-

NET PROFIT OF THE PERIOD

1,151,991

370,326

298,934

615,550

5,254

189,563

(505,545)

(67,321)

 

9

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex I - 2Q17

Financial Information of the Subsidiaries

STATEMENT OF INCOME 06/30/2017

ED Rondonia

ED Piauí

ED Alagoas

ED Acre

ED Roraima

Amazonas D

 

 

 

 

 

 

 

Operational Revenue

571,749

671,080

728,332

235,139

181,143

1,297,783

 

 

 

 

 

 

 

Supply (sell) of electric energy - Generation

-

-

-

-

-

-

Supply of electric energy - Generation

-

-

-

-

-

-

Short Term electric Energy - Generation

-

-

-

-

-

-

 

 

 

 

 

 

 

Electric Energy Supply - Distribution

721,723

490,969

867,122

285,387

212,158

1,372,985

Short Term Electric Energy - Distribution

62,176

13,467

-

62,913

-

240,592

Construction Revenue - Distribution

80,114

57,903

52,509

8,741

9,471

78,447

Regulatory Asset and Liability (Installment A – CVA)

- 883

68,281

137,701

- 5,944

17,856

- 38,044

 

 

 

 

 

 

 

Other Operational Revenues

19,233

402,083

48,143

8,521

14,134

28,334

 

 

 

 

 

 

 

Deductions to Operational Revenues

- 310,614

- 361,623

- 377,143

- 124,479

- 72,476

- 384,531

 

 

 

 

 

 

 

Operational Expenses

- 813,665

- 788,418

- 804,830

- 288,801

- 251,859

(980,707)

 

 

 

 

 

 

 

Personnel, Supplies and Services

- 136,558

- 181,628

- 145,180

- 51,411

- 65,324

- 315,858

Energy Purchased for Resale

- 896,680

- 485,823

- 511,149

- 260,548

- 124,749

- 958,963

Charges upon use of eletricity network

- 9,323

- 29,110

- 25,302

- 3,922

-

- 16,629

Construction

- 80,114

- 57,903

- 52,509

- 8,741

- 9,471

- 78,447

Electric Energy production cost

321,840

-

-

99,336

- 24,482

183,813

Donations and Contributions

- 162

-

- 83

-

-

-

Depreciation and Amortization

- 20,337

- 23,618

- 22,168

- 12,622

- 5,126

- 76,577

Operating Provisions

28,461

24,922

- 38,147

- 25,511

- 19,838

339,632

Others

- 20,792

- 35,258

- 10,292

- 25,382

- 2,869

- 57,678

 

 

 

 

 

 

 

OPERATING RESULT BEFORE FINANCIAL RESULT

(241,916)

(117,338)

(76,498)

(53,662)

(70,716)

317,076

 

 

 

 

 

 

 

FINANCIAL REVENUES (EXPENSES)

 

 

 

 

 

 

 

 

 

 

 

 

 

Financial Investment Revenues

906

16

2,903

714

685

4,754

Interest, Commission and Rates revenue (loans and financing)

-

-

-

-

-

-

Moratorium Increase on electric energy

18,486

45,707

13,943

5,857

- 34,806

31,268

Net Monetary Updates

220,999

5,608

5,563

8,503

18,791

236,123

Net Exchange Updates

-

-

-

-

-

871

Net Regulatory Asset (Installment A – CVA)

2,329

1,563

- 551

-

547

- 11,940

Others Financial Revenues

- 842

1,452

- 723

951

4,867

8,652

Debt Charges - financing and loans

- 67,752

- 128,467

- 114,562

- 17,691

- 1,058

- 177,967

Debt Charges - accounts payable

-

-

-

-

-

- 896,070

Charges – leasing

-

-

-

-

-

- 161,219

Passive monetary variation

- 275,703

- 121,723

- 5,344

- 31,078

- 18,748

-

Passive exchange variation

-

-

- 20

-

-

-

Net Regulatory Liability (Installment A – CVA)

- 2,955

-

1,414

-

- 346

- 2,623

Others Financial Expenses

- 44,909

- 17,946

- 31,076

- 81,036

-

- 117,638

 

 

 

 

 

 

 

FINANCIAL RESULT

(149,441)

(213,790)

(128,453)

(113,780)

(30,069)

(1,085,789)

 

 

 

 

 

 

 

EQUITY PARTICIPATIONS RESULT

-

-

-

-

-

-

 

 

 

 

 

 

 

RESULT BEFORE SOCIAL CONTRIBUTION, INCOME TAX, EMPLOYEES AND MANAGEMENT PARTICIPATION AND MINORITY PARTICIPATION

(391,357)

(331,128)

(204,951)

(167,442)

(100,785)

(768,713)

 

 

 

 

 

 

 

Income Tax and Social Contribution and Fiscal Incentives Revenue

88,051

282,543

82,890

33,848

-

-

 

 

 

 

 

 

 

RESULT BEFORE EQUITY PARTICIPATIONS

(303,306)

(48,585)

(122,061)

(133,594)

(100,785)

(768,713)

 

 

 

 

 

 

 

Minority Participation

-

-

-

-

-

-

NET PROFIT OF THE PERIOD

(303,306)

(48,585)

(122,061)

(133,594)

(100,785)

(768,713)

 

 

 

10

 
 
 
 

DFR - Investor Relations Superintendence

Marketletter - Annex I - 2Q17

Financial Information of the Subsidiaries

STATEMENT OF INCOME 06/30/2016

Furnas

Chesf

Eletrosul

Eletronorte

Eletropar

Eletronuclear

CGTEE

Amazonas GT

 

 

 

 

 

 

 

 

 

Operational Revenues

15,342,752

10,328,165

2,229,482

5,310,123

355

1,272,325

243,839

155,356

 

 

 

 

 

 

 

 

 

Electric Energy Supply (sell) - Generation

1,726,231

82,691

342,774

1,417,135

-

1,450,851

265,078

268,348

Electric Energy Supply - Generation

-

391,908

11,536

528,754

-

-

-

-

Short Term Electric Energy - Generation

63,431

30,608

3,969

223,567

-

-

-

-

Renewed Plants Operation and Maintenance Revenue - Generation

402,854

617,184

-

7,289

-

-

-

-

Construction Plants Revenue - Generation

- 18,385

18,878

-

-

-

-

-

-

Financial – Return on Investment - Generation

-

-

-

-

-

-

-

-

Renewed Lines Operation and Maintenance Revenue - Transmission

539,884

456,914

309,956

219,787

-

-

-

-

Operation and Maintenance Revenue - Transmission

32,698

36,856

49,641

1,966

-

-

-

-

Construction Revenue - Transmission

230,189

360,929

58,825

135,743

-

-

-

-

Financial – Return on Investment - Transmission

12,796,768

8,641,318

1,540,349

3,191,930

-

-

-

-

Others Operational Revenues

17,022

23,612

12,065

98,473

355

-

2,169

-

 

 

 

 

 

 

 

 

 

Deductions to Operational Revenues

- 447,940

- 332,733

- 99,633

- 514,521

-

- 178,526

- 23,408

- 112,992

 

 

 

 

 

 

 

 

 

Operational Expenses

- 2,109,656

- 1,715,018

- 562,601

- 1,630,292

- 4,071

- 4,981,503

(341,831)

(236,513)

 

 

 

 

 

 

 

 

 

Personnel, Supplies and Services

- 906,428

- 584,385

- 253,160

- 750,106

- 1,991

- 362,676

- 131,125

- 77,385

Energy Purchased for Resale

- 277,271

- 194,757

- 129,325

- 83,739

-

-

- 94,561

-

Charges upon use of eletricity network

- 234,832

- 318,434

- 11,607

- 247,306

-

- 43,731

- 20,669

- 5,417

Construction

- 211,804

- 379,807

- 58,825

- 135,743

-

-

-

-

Electric Energy production cost

- 222,467

- 7,803

-

- 3,717

-

- 193,035

- 22,933

103,909

Donations and Contributions

- 14,415

- 5,634

-

- 9,165

-

-

-

-

Depreciation and Amortization

- 137,781

- 50,659

- 82,116

- 225,644

- 15

- 197,522

- 36,247

- 31,670

Operating Provisions

31,523

- 80,394

- 7,053

- 161,127

- 1,186

- 4,123,190

- 5,974

- 648

Others

- 136,181

- 93,145

- 20,515

- 13,745

- 879

- 61,349

- 30,322

- 225,302

 

 

 

 

 

 

 

 

 

OPERATING RESULT BEFORE FINANCIAL RESULT

13,233,096

8,613,147

1,666,881

3,679,831

(3,716)

(3,709,178)

(97,992)

(81,157)

 

 

 

 

 

 

 

 

 

FINANCIAL REVENUES (EXPENSES)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Revenue from financial investments

54,440

36,010

22,005

62,139

4,913

883

1,844

12,418

Interest, Commission and Rates revenue (loans and financing)

31,850

-

-

-

-

-

-

-

Moratorium Increase on electric energy

8,553

46,483

-

53,608

-

-

-

-

Net Monetary Updates

83,170

14,766

49,413

118,915

-

3,112

2,621

8,601

Net Exchange Updates

- 5,803

-

53,110

127,953

-

18,691

166

-

Derivatives

-

-

-

121,641

-

-

-

-

Others Financial Revenues

54,943

57,853

48,636

23,212

-

1,813

260

6,884

Debt Charges - financing and loans

- 495,773

- 71,228

- 241,027

- 313,002

-

- 44,791

- 209,225

- 123,676

Debt Charges - accounts payable

-

-

- 4,939

-

-

-

-

-

Charges – shareholders remuneration

-

-

- 2,601

-

-

-

- 5,042

-

Passive monetary variation

- 202,633

- 6,532

- 52,661

- 57,063

-

- 40,515

-

- 30,793

Passive exchange variation

93,128

-

- 11,108

- 36,475

-

- 60,497

- 51

-

Losses on derivatives

-

-

-

-

-

-

-

-

Others Financial Expenses

- 77,908

- 28,791

- 46,200

- 21,632

- 603

- 122,971

- 5,470

- 14,389

 

 

 

 

 

 

 

 

 

FINANCIAL RESULT

(456,033)

48,561

(185,372)

79,296

4,310

(244,275)

(214,897)

(140,955)

 

 

 

 

 

 

 

 

 

EQUITY PARTICIPATION RESULT

37,983

33,105

(72,534)

29,122

3,204

-

-

-

 

 

 

 

 

 

 

 

 

RESULT BEFORE SOCIAL CONTRIBUTION, INCOME TAX, EMPLOYEES AND MANAGEMENT PARTICIPATION AND MINORITY PARTICIPATION

12,815,046

8,694,813

1,408,975

3,788,249

3,798

(3,953,453)

(312,889)

(222,112)

 

 

 

 

 

 

 

 

 

Income Tax and Social Contribution and Fiscal Incentives Revenue

- 4,344,719

- 2,957,481

- 504,207

- 1,106,295

- 412

- 72,249

-

- 14,230

 

 

 

 

 

 

 

 

 

RESULT BEFORE EQUITY PARTICIPATIONS

8,470,327

5,737,332

904,768

2,681,954

3,386

(4,025,702)

(312,889)

(236,342)

 

 

 

 

 

 

 

 

 

Minority Participation

- 19

-

- 1,542

-

-

-

-

-

NET PROFIT OF THE PERIOD

8,470,346

5,737,332

903,226

2,681,954

3,386

(4,025,702)

(312,889)

(236,342)

 

 

11

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex I - 2Q17

Financial Information of the Subsidiaries

STATEMENT OF INCOME 06/30/2016

ED Rondonia

ED Piauí

ED Alagoas

ED Acre

ED Roraima

Amazonas D

 

 

 

 

 

 

 

Operational Revenue

855,985

610,224

707,706

228,134

131,930

1,370,326

 

 

 

 

 

 

 

Supply (sell) of electric energy

-

-

-

-

15,242

-

Supply of electric energy - Generation

-

-

-

-

-

-

Short Term electric Energy

-

-

-

-

-

-

Plants Construction Revenue

-

-

-

-

-

4,304

 

 

 

 

 

 

 

Electric Energy Supply - Distribution

838,481

829,429

971,057

282,940

139,561

1,471,329

Short Term Electric Energy - Distribution

32,074

-

-

-

-

169,927

Construction Revenue - Distribution

106,203

50,723

65,772

31,816

10,108

107,508

Regulatory Asset and Liability (Installment A – CVA)

222,607

22,307

- 44,743

17,237

- 36

- 56,944

 

 

 

 

 

 

 

Other Operational Revenues

43,859

80,990

95,813

15,932

4,287

146,244

 

 

 

 

 

 

 

Deductions to Operational Revenues

- 387,239

- 373,225

- 380,193

- 119,791

- 37,232

- 472,042

 

 

 

 

 

 

 

Operational Expenses

- 840,134

- 741,737

- 737,010

- 284,591

- 252,744

(1,855,296)

 

 

 

 

 

 

 

Personnel, Supplies and Services

- 123,966

- 143,871

- 113,090

- 45,185

- 43,261

- 281,598

Electric Energy puchased for resale

- 537,744

- 428,822

- 431,470

- 122,936

- 92,791

- 867,702

Charges on Eletric Energy Grid Usage

- 8,863

- 52,709

- 41,571

- 2,525

-

- 42,890

Construction

- 106,203

- 50,723

- 65,772

- 31,816

- 10,108

- 111,812

Fuel used for electric energy production

-

-

-

- 31,404

- 68,388

69,303

Remuneration and Reimbursement (Royalties)

- 180

-

- 84

-

-

-

Depreciation and Amortization

- 19,170

- 19,126

- 18,232

- 8,424

- 5,439

- 50,901

Operating Provisions

- 18,749

99,904

- 3,990

- 4,595

- 31,028

- 377,755

Others

- 25,259

- 146,390

- 62,801

- 37,706

- 1,729

- 191,941

 

 

 

 

 

 

 

OPERATING RESULT BEFORE FINANCIAL RESULT

15,851

(131,513)

(29,304)

(56,457)

(120,814)

(484,970)

 

 

 

 

 

 

 

FINANCIAL REVENUES (EXPENSES)

 

 

 

 

 

 

 

 

 

 

 

 

 

Financial Investment Revenues

3,295

13

2,379

329

236

2,576

Interest, Commission and Rates revenue (loans and financing)

-

-

-

-

-

-

Moratorium Increase on electric energy

22,813

36,761

10,108

11,490

- 23,597

47,797

Net Monetary Updates

245,652

9,563

10,499

12,304

16,930

5,684

Net Exchange Updates

-

-

-

-

-

-

Net Regulatory Asset (Installment A – CVA)

6,610

4,954

15,282

-

98

- 3,119

Others Financial Revenues

- 38,541

- 30

- 652

3

7,310

619,053

Debt Charges - financing and loans

- 53,987

- 97,190

- 96,781

- 20,575

- 4,571

- 105,896

Debt Charges - accounts payable

-

-

-

-

-

-

Charges – leasing

-

-

-

-

-

- 152,762

Passive monetary variation

- 294,824

- 47,566

- 4,559

- 57,070

- 24,622

-

Passive exchange variation

-

-

330

-

-

- 3,256

Net Regulatory Liability (Installment A – CVA)

- 9,604

-

- 3,727

-

-

- 2,445

 

- 27,147

- 15,414

- 11,707

- 5,557

-

- 1,034,018

 

 

 

 

 

 

 

FINANCIAL RESULT

- 145,733

- 108,909

- 78,828

- 59,076

- 28,215

- 626,386

 

 

 

 

 

 

 

EQUITY PARTICIPATIONS RESULT

-

-

-

-

-

- 193,544

 

 

 

 

 

 

 

RESULT BEFORE SOCIAL CONTRIBUTION, INCOME TAX, EMPLOYEES AND MANAGEMENT PARTICIPATION AND MINORITY PARTICIPATION

(129,882)

(240,422)

(108,132)

(115,533)

(149,029)

(1,304,900)

 

 

 

 

 

 

 

Income Tax and Social Contribution and Fiscal Incentives Revenue

-

-

-

-

-

-

 

 

 

 

 

 

 

RESULT BEFORE EQUITY PARTICIPATIONS

(129,882)

(240,422)

(108,132)

(115,533)

(149,029)

(1,304,900)

 

 

 

 

 

 

 

Minority Participation

-

-

-

-

-

-

NET PROFIT OF THE PERIOD

(129,882)

(240,422)

(108,132)

(115,533)

(149,029)

(1,304,900)

 

 

12

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex I - 2Q17

Financial Information of the Subsidiaries

CASH FLOW 06/30/2017

Furnas

Chesf

Eletrosul

Eletronorte

Eletronuclear

CGTEE

Eletropar

Amazonas GT

Operating Activities

 

 

 

 

 

 

 

 

Profit (loss) before income tax and social contribution

1,762,018

619,432

425,180

711,393

239,961

- 505,545

5,286

- 1,531

 

 

 

 

 

 

 

 

 

Depreciation and Amortization

129,783

49,206

90,034

225,222

198,067

33,557

12

31,317

Net monetary variation

54,459

-

28,671

- 44,087

3,445

-

-

7,630

Net exchange variation

8,434

- 5,293

19,904

- 2,005

13,364

- 23

-

-

Financial Charges

603,978

141,236

209,095

305,274

41,442

240,759

-

133,650

Equity Result

- 43,487

- 46,229

- 48,360

- 80,275

-

-

- 5,102

-

Provision for uncovered liability

-

-

-

-

-

-

-

-

Provision for doubtful credit liquidation

- 2,670

13,022

1,017

31,193

3,010

-

-

-

Provisions for contingencies

- 32,872

146,519

252

51,334

59,664

74,719

-

- 435

Provision for staff realignment

-

-

-

-

-

-

-

-

Provision for loss on Investments

- 2,322

-

-

-

-

-

-

-

Provision for reduction on recoverable amount of Investment

-

1,647

- 217,148

31,260

484,641

-

-

-

Provision for onerous contracts

- 192,310

-

-

-

- 484,641

-

-

-

Provision for loss with Financial Asset

-

-

-

-

-

-

-

-

Global reversal reserve charges

-

-

-

-

-

-

-

-

Adjustment to Present Value / Market Value

-

-

686

-

41,597

-

-

-

Minority Participation in Result

- 15,388

-

-

-

-

-

-

-

Charges on Shareholders funds

-

-

5,077

-

-

4,831

-

-

Financial Asset Revenue

- 1,735,487

- 771,005

- 249,688

- 561,108

-

-

-

- 193,499

Derivatives

-

-

-

- 68,892

-

-

-

-

Others

154,618

233,758

- 300,183

155,757

274,468

5

-

-

(Increase) decrease on operating asset/liability

697,303

- 180,627

- 377,602

475,565

- 386,452

111,450

10,080

103,775

 

 

 

 

 

 

 

 

 

Cash from Operating Activities

1,386,057

201,666

- 413,065

1,230,631

488,566

- 40,247

10,276

80,907

 

 

 

 

 

 

 

 

 

Payment of financial charges

- 826,200

- 130,846

- 305,938

- 209,569

- 133,908

- 184

-

- 64,649

Payment of charges of global reversal reserve

-

-

-

-

-

-

-

-

Financial charges receivable

48

-

53

-

-

-

-

-

Remuneration from equity investments received

111,810

29,125

2,660

29,522

-

-

1,973

-

Annual allowed Revenue Receiving (Financial Asset)

146,191

- 93,200

499,326

233,093

-

-

-

-

Financial Asset Indemnities Receiving

-

-

-

-

-

-

-

-

Payment of income tax and social contribution

- 251,015

- 989

- 1,591

- 293,855

- 34,905

-

- 32

-

Complementary pension fund payment

- 31,942

- 119,187

- 3,494

-

-

-

-

-

Payment of lawsuit contingencies

-

- 32,139

-

-

-

-

-

-

Lawsuit Deposits

2,074

507,004

- 12,433

-

- 6,884

- 3,507

-

- 30,645

 

 

 

 

 

 

 

 

 

Net Cash from Operating Activities

537,023

361,434

- 234,482

989,822

312,869

- 43,938

12,218

- 14,387

 

 

 

 

 

 

 

 

 

Financing Activities

 

 

 

 

 

 

 

 

Loans and financing obtained

261,000

450,164

690,000

500,322

160,000

8,576

-

27,072

Loans and financing payable - principal

- 595,872

- 487,897

- 352,823

- 415,071

- 39,506

- 4,871

-

-

Payment to Shareholders

-

-

- 58

-

-

-

- 8,465

-

Payment of refinancing of taxes and contributions - Principal

- 51,019

-

- 7,764

-

-

-

-

-

Global Reversion Reserve Replacement

-

-

-

-

-

-

-

-

 

-

27,000

1

-

-

-

-

-

 

- 11

158,958

-

-

-

-

-

-

Net Cash from Financing Activities

- 385,902

148,225

329,356

85,251

120,494

3,705

- 8,465

27,072

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Investment Activities

 

 

 

 

 

 

 

 

 

-

-

-

-

-

-

-

-

Receiving of Loans and Financing Ceded

14,360

-

-

-

-

-

-

-

Acquisition of property, unit and equipment

- 35,207

- 128,850

- 6,044

- 11,853

- 315,335

- 2,075

-

- 30,854

Acquisition of intangible assets

- 5,983

- 2,281

- 1,720

-

- 1,829

- 290

- 9

-

Acquisition of concession assets

- 105,034

-

- 35,929

- 28,655

-

-

-

-

Concession for advance of future capital increase

- 3,429

-

- 12,452

254

-

-

-

-

Acquisition/Contribution of capital in equity participation

- 425,341

- 197,412

- 31,597

- 336,696

-

-

-

-

Concession for Future Capital Increase

-

-

-

-

-

-

-

-

Others

426,330

- 15,136

16

- 664,531

- 121,663

-

-

-

 

 

 

 

 

 

 

 

 

Net Cash from investments activities

- 134,304

- 343,679

- 87,726

- 1,041,481

- 438,827

- 2,365

- 9

- 30,854

 

 

 

 

 

 

 

 

 

Increase (decrease) in cash and cash equivalents

16,817

165,980

7,148

33,592

- 5,464

- 42,598

3,744

- 18,169

Cash and cash equivalent – beginning of period

35,220

140,399

36,843

8,992

15,323

56,007

499

23,622

Cash and cash equivalent – end of period

52,037

306,379

43,991

42,584

9,859

13,409

4,241

5,453

 

16,817

165,980

7,148

33,592

- 5,464

- 42,598

3,742

- 18,169

 

13

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex I - 2Q17

Financial Information of the Subsidiaries

CASH FLOW 06/30/2017

ED Alagoas

ED Rondônia

ED Piauí

ED Roraima

ED Acre

Amazonas Energia

 

 

 

 

 

 

 

Operating Activities

 

 

 

 

 

 

Profit (loss) before income tax and social contribution

- 204,951

- 391,357

- 331,128

- 100,785

- 167,442

- 768,713

 

 

 

 

 

 

 

Depreciation and amortization

22,168

20,337

23,618

5,126

12,622

76,577

Net monetary variation

- 219

54,704

1,525

-

- 22,116

- 1,283

Net exchange variation

20

-

-

-

-

- 871

Financing charges

114,562

67,752

120,659

1,058

18,150

339,186

Equity Method Result

-

-

-

-

-

-

Provision for uncovered liability

-

-

-

-

-

67,321

Provision for doubtful credit liquidation

3,240

6,195

6,141

12,094

356

138,284

Provisions for contingencies

16,437

54,642

47,070

7,651

318

- 19,936

Provision for staff realignment

-

-

-

-

-

-

Provision for loss with Investments

-

-

-

-

-

-

Provision for reduction on recoverable amount of Investment

- 12,855

- 24,918

- 45,442

-

-

- 32,274

Provision for onerous contracts

-

- 88,367

- 32,691

-

-

- 433,795

Provision for loss with Financial Asset

-

-

-

-

-

-

Global reversal reserve charges

-

-

-

-

-

-

Adjustment to Present Value / Market Value

33

-

-

-

-

-

Minority Participation in Result

-

-

-

-

-

-

Charges on Shareholders funds

-

-

-

-

-

-

Financial Asset Revenue

-

-

-

-

-

-

Derivatives

-

-

-

-

-

-

Others

504,304

45,918

-

513

33,848

735,927

(Increase) decrease on operating asset/liability

- 594,974

200,684

32,947

- 5,082

109,108

- 284,651

 

 

 

 

 

 

 

Cash from Operating Activities

- 152,235

- 54,410

- 177,301

- 79,425

- 15,156

- 184,228

 

 

 

 

 

 

 

Payment of financial charges

-

- 6,477

- 17,616

- 1,058

- 2,231

- 27,279

Payment of charges of global reversal reserve

-

-

-

-

-

-

Financial charges receivable

-

-

-

-

-

-

Remuneration from equity investments received

-

-

-

-

-

-

Annual allowed Revenue Receiving (Financial Asset)

-

-

-

-

-

-

Financial Asset Indemnities Receiving

-

-

-

-

-

-

Payment of income tax and social contribution

82,890

-

-

-

-

-

Complementary pension fund payment

-

-

-

-

-

-

Payment of lawsuit contingencies

-

-

- 33,083

-

- 19,466

-

Lawsuit Deposits

- 13,841

- 4,295

- 8,898

- 9,555

- 2,949

- 26,440

 

 

 

 

 

 

 

Net Cash from Operating Activities

- 83,186

- 65,182

- 236,898

- 90,038

- 39,802

- 237,947

 

 

 

 

 

 

 

Financing Activities

 

 

 

 

 

 

Loans and financing obtained

195,673

163,022

297,109

66,684

58,662

473,530

Loans and financing payable - principal

- 16,421

- 10,006

- 14,542

- 949

- 4,092

- 53,566

Payment to Shareholders

-

-

-

-

-

-

Global Reversal Reserve Replacement

-

-

-

-

-

-

Receiving of advance for future capital increase (AFAC)

-

-

13,576

-

-

-

Payment of refinancing of taxes and contributions – Principal

- 4,258

-

-

-

-

-

Others

-

-

-

-

-

-

Net Cash from Financing Activities

174,994

153,016

296,143

65,735

54,570

419,964

 

 

 

 

 

 

 

Investment Activities

 

 

 

 

 

 

 

 

 

 

 

 

 

Financing and Loans Concessions

-

-

-

-

-

-

Receiving of Loans and Financing Ceded

-

-

-

-

-

-

Acquisition of property, unit and equipment

- 476

- 770

- 710

3,965

- 739

- 5,565

Acquisition of intangible assets

- 2,595

- 1,605

- 2,351

- 245

- 884

- 86,744

Acquisition of concession assets

- 39,262

- 66,898

- 54,842

- 8,262

- 8,636

- 80,953

Concession for advance of future capital increase

-

-

-

-

-

-

Acquisition/Contribution of capital in equity participation

-

-

-

-

-

-

Others

1,388

259

-

-

- 2,078

-

Net Cash from investments activities

- 40,945

- 69,014

- 57,903

- 4,542

- 12,337

- 173,262

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Increase (decrease) in cash and cash equivalents

50,863

18,820

1,342

- 28,845

2,431

8,755

Cash and cash equivalent – beginning of period

21,804

18,706

5,200

35,598

16,006

71,343

Cash and cash equivalent – end of period

72,667

37,526

6,542

6,755

18,437

80,098

 

50,863

18,820

1,342

- 28,843

2,431

8,755

 

 

14

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex I - 2Q17

Financial Information of the Subsidiaries

CASH FLOW 06/30/2016

Furnas

Chesf

Eletrosul

Eletronorte

Eletronuclear

CGTEE

Eletropar

Amazonas GT

Operating Activities

 

 

 

 

 

 

 

 

Profit (loss) before income tax and social contribution

12,815,046

8,694,813

1,408,975

3,788,249

- 3,953,453

- 312,889

3,798

- 222,112

 

 

 

 

 

 

 

 

 

Depreciation and amortization

137,781

50,659

82,116

225,644

197,522

38,895

15

31,670

Monetary net variation

119,463

- 13,954

6,509

- 61,852

38,868

- 2,621

-

22,192

Exchange net variation

- 87,325

5,720

- 42,002

- 91,478

41,806

- 115

-

-

Financing charges

617,070

71,228

192,775

313,002

67,985

205,029

-

123,676

Equity Method Result

- 37,983

- 33,105

72,534

- 29,122

-

-

- 3,204

-

Provision for uncovered liability

-

-

-

-

-

-

-

-

Provision for doubtful credit liquidation

- 2,267

51,864

160

21,948

-

-

-

-

Provisions for contingencies

105,420

116,369

7,904

- 24,630

18,219

4,566

-

648

Provision for staff realignment

-

-

-

-

-

-

-

-

Provision for investment loss

-

-

-

-

-

-

1,186

-

Provision for reduction on recoverable amount of Investment

-

- 66,255

-

-

2,414,479

-

-

-

Provision for onerous contracts

- 134,674

- 21,584

-

-

1,677,269

-

-

-

Provision for loss with Financial Asset

-

-

-

-

-

-

-

-

Global reversal reserve charges

-

-

-

-

-

-

-

-

Adjustment to Present Value / Market Amount

-

-

-

-

41,330

-

-

-

Minority Participation in Result

19

-

-

-

-

-

-

-

Charges on Shareholders funds

-

-

2,601

-

-

5,042

-

-

Financial Asset Revenue

- 12,796,768

- 8,641,318

- 1,540,349

- 3,191,930

-

-

-

-

Derivatives

-

-

-

- 121,641

-

-

-

-

Others

- 71,002

- 4,420

- 344,641

66,234

284,004

1

-

-

(Increase) decrease on operating asset/liability

54,596

95,335

- 13,429

- 531,431

- 635,272

- 141,911

3,443

151,405

 

 

 

 

 

 

 

 

 

Cash from Operating Activities

719,376

305,352

- 166,847

362,993

192,757

- 204,003

5,238

107,479

 

 

 

 

 

 

 

 

 

Payment of financial charges

- 519,033

- 74,207

- 116,899

- 170,611

- 87,081

- 8,107

-

- 28,393

Payment of charges of global reversal reserve

-

-

-

-

-

-

-

-

Financial charges receivable

236

-

136

-

-

-

-

-

Remuneration from equity investments received

114,869

40,462

1,916

25,914

-

-

3,476

-

Annual allowed Revenue Receiving (Financial Asset)

127,429

- 303,943

470,430

234,620

-

-

-

-

Financial Asset Indemnities Receiving

-

-

-

-

-

-

-

-

Payment of income tax and social contribution

- 203,105

- 938

- 493

- 86,445

- 53,697

-

- 412

-

Complementary pension fund payment

- 5,782

- 47,736

- 3,309

-

-

-

-

-

Payment of lawsuit contingencies

-

- 6,193

-

- 3,414

-

-

-

-

Lawsuit Deposits

- 141,004

- 140,857

- 25,986

- 14,556

- 814

- 224

-

2,827

 

 

 

 

 

 

 

 

 

Net Cash from Operating Activities

92,986

- 228,060

158,948

348,501

51,165

- 212,334

8,303

81,913

 

 

 

 

 

 

 

 

 

Financing Activities

 

 

 

 

 

 

 

 

Loans and financing obtained

875,675

119,898

748,372

417,655

611,000

-

-

-

Loans and financing payment - principal

- 377,790

- 167,942

- 810,552

- 428,738

- 71,291

- 11,534

-

-

Payment to Shareholders

-

-

- 2,500

-

-

-

- 5,361

-

Payment of Refinancing of taxes and contribution - principal

- 52,468

-

-

-

-

-

-

-

Global Reversal Reserve Replacement

-

-

-

-

-

-

-

-

 

-

-

6

-

-

241,824

-

-

 

-

- 47,478

-

-

-

-

-

-

Net Cash from Financing Activities

445,417

- 95,522

- 64,674

- 11,083

539,709

230,290

- 5,361

-

 

 

 

 

 

 

 

 

 

Investment Activities

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Financing and Loans Concessions

-

-

-

-

-

-

-

-

Receiving of Loans and Financing Ceded

14,134

-

-

-

-

-

-

-

Acquisition of fixed assets

- 39,598

- 158,718

- 75,965

- 37,415

- 620,791

- 4,587

- 5,793

- 79,593

Acquisition of intangible assets

- 3,532

- 2,286

- 2,106

- 1,732

- 1,329

- 1,091

-

-

Acquisition of concession assets

- 211,803

-

- 55,821

- 145,115

-

-

-

-

Concession for advance of future capital increase

- 23,418

-

- 150,473

- 72,039

-

-

-

-

Acquisition/Contribution of capital in equity participation

- 603,305

- 223,189

- 58,000

- 689,111

-

-

-

-

Concession for advance of future capital increase

-

-

-

-

-

-

-

-

Others

336,196

482,708

240,739

555,895

26,148

-

-

-

Net Cash from Investments activities

- 531,326

98,515

- 101,626

- 389,517

- 595,972

- 5,678

- 5,793

- 79,593

 

 

 

 

 

 

 

 

 

Increase (decrease) in cash and cash equivalents

7,077

- 225,067

- 7,352

- 52,099

- 5,098

12,278

- 2,852

2,320

Cash and cash equivalent – beginning of period

12,099

373,867

33,490

70,633

6,884

5,190

5,388

38,170

Cash and cash equivalent – end of period

19,176

148,800

26,138

18,534

1,786

17,468

2,537

40,490

 

7,077

- 225,067

- 7,352

- 52,099

- 5,098

12,278

- 2,851

2,320

 

15

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex I - 2Q17

Financial Information of the Subsidiaries

CASH FLOW 06/30/2016

ED Alagoas

ED Rondônia

ED Piauí

ED Acre

ED Roraima

Amazonas Energia

Operating Activities

 

 

 

 

 

 

Profit (loss) before income tax and social contribution

- 108,132

- 129,882

- 240,422

- 149,030

- 115,533

- 1,304,901

 

 

 

 

 

 

 

Depreciation and amortization

18,232

19,170

19,126

5,439

8,424

50,901

Net monetary variation

3,715

14,956

1,393

-

- 44,766

- 2,428

Net exchange variation

- 330

-

-

-

-

-

Financing charges

96,992

53,987

94,587

4,571

20,575

258,658

Equity Result

-

-

-

-

-

193,544

Provision for uncovered liability

-

-

-

-

-

43,675

Provision for doubtful credit liquidation

- 13,445

12,267

29,915

32,380

4,138

127,392

Provisions for contingencies

10,517

6,482

9,541

- 1,352

457

195,659

Provision for staff realignment

-

-

-

-

-

-

Provision for loss with Investment

-

-

-

-

-

-

Provision for reduction on recoverable amount of assets

-

-

- 18,907

-

-

-

Provision for onerous contracts

-

-

-

-

-

-

Provision for loss with Financial Asset

-

-

-

-

-

-

Global reversal reserve charges

-

-

-

-

-

-

Adjustment to Present Value / Market Amount

- 89

-

-

-

-

-

Minority Participation in Result

-

-

-

-

-

-

Financial charges on Shareholders funds

-

-

-

-

-

-

Financial Asset Revenue

-

-

-

-

-

-

Derivatives

-

-

-

-

-

-

Others

423,124

21,893

-

663

23

785,185

(Increase) decrease on operating asset/liability

- 359,975

196,872

156,254

125,196

152,912

- 142,280

 

 

 

 

 

 

 

Cash from Operating Activities

70,609

195,745

51,487

17,867

26,230

205,405

 

 

 

 

 

 

 

Payment of financial charges

- 1,053

- 15,921

-

- 2,016

- 2,774

- 26,599

Payment of charges of global reversal reserve

-

-

-

-

-

-

Financial charges receivable

-

-

-

-

-

-

Remuneration from equity investments received

-

-

-

-

-

-

Annual allowed Revenue Receiving (Financial Asset)

-

-

-

-

-

-

Financial Asset Indemnities Receiving

-

-

-

-

-

-

Payment of income tax and social contribution

-

-

-

-

-

-

Complementary pension fund payment

-

-

-

-

-

-

Payment of contingent liabilities

-

-

- 8,598

-

-

-

Lawsuit Deposits

-

- 33,235

-

-

-

- 48,447

 

 

 

 

 

 

 

Net Cash from Operating Activities

69,556

146,589

42,889

15,851

23,456

130,359

 

 

 

 

 

 

 

Financing Activities

 

 

 

 

 

 

Loans and financing obtained

3,794

16,109

-

5,968

7,505

-

Loans and financing payment - principal

- 22,481

- 24,418

-

- 3,295

-

- 30,441

Payment to Shareholders

-

-

-

-

-

-

Global Reversal Reserve Reposition

-

-

-

-

-

-

Receiving of advance for future capital increase (AFAC)

-

-

-

-

-

-

 

- 5,891

-

-

-

-

-

 

-

-

- 254

-

-

3,257

Net Cash from Financing Activities

- 24,578

- 8,309

- 254

2,673

7,505

- 27,184

 

 

 

 

 

 

 

Investment Activities

 

 

 

 

 

 

 

 

 

 

 

 

 

Financing and Loans Concessions

-

-

-

-

-

-

Receiving of Loans and Financing Ceded

-

-

-

-

-

-

Acquisition of fixed assets

- 556

- 2,881

- 1,339

- 4,447

- 248

- 14,028

Acquisition of intangible assets

- 2,703

- 4,220

- 1,771

- 1,573

- 1,092

- 110

Acquisition of concession assets

- 45,608

- 136,439

- 45,049

- 9,673

- 30,710

- 123,683

Concession for advance of future capital increase

-

-

-

-

-

-

Acquisition/Contribution of capital in equity participation

-

-

-

-

-

-

Others

1,303

-

-

-

- 9,598

-

 

 

 

 

 

 

 

Net Cash from investments activities

- 47,564

- 143,540

- 48,159

- 15,693

- 41,648

- 137,821

 

 

 

 

 

 

 

Increase (decrease) in cash and cash equivalents

- 2,586

- 5,260

- 5,524

2,831

- 10,687

- 34,646

Cash and cash equivalent – beginning of period

22,801

25,400

9,209

3,686

18,501

68,251

Cash and cash equivalent – end of period

20,215

20,140

3,685

6,517

7,814

33,605

 

- 2,586

- 5,260

- 5,524

2,831

- 10,687

- 34,646

 

 

 

16

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex II - 2Q17

Financial Information of the Subsidiaries

CHESF

        

Result Analysis

        

 

        

The Company had in 2Q17 a result 97% smaller than the one recorded in 2Q16, going from a profit of R$ 5,745 million in 2Q16 to a profit of R$ 160 million in 2Q17, mainly due to the reasons described below.

Operating Revenue

       

 

        

The Net Operating Revenue had a decrease of 86.3% in 2Q17, compared to the 2Q16, going from R$ 9,469 million in 2Q16 to R$ 1,296 million in 2Q17. The variations of each income account are detailed below:

         

Gross Revenue - R$ Thousand

2Q17

2Q16

Variation (%)

Analysis

Generation

 

 

 

 

Supply of energy to distribution companies

30,178

38,596

-21.8

The variation was mainly due to: (i) Movement in the auction contracts carried out in the ACL, due to the seasonalization of the purchase of energy in 2017 and the annual readjustment.

Supply of energy to final consumers

225,127

200,190

12.5

The variation was mainly due to: (i) Mainly due to the adjustments of contracts postponed with industrial consumers, as well as the annual adjustment.

Short Term Market (CCEE)

130,778

20,565

535.9

The variation was mainly due to: (i) Mainly the strategy of seasonal electricity consumption and the allocation of more energy over the 1st half of 2017, in addition to the market variations (PLD, GSF, Portfolio of contracts etc.); and (ii) The liquidation connected to April 2017, charges (ESS) were returned since April 2013 owing to an injunction in favor of CHESF.

O&M Income - Upgraded Power Plants Law 12.783/2013

328,937

308,028

6.8

The variation was mainly due to: (i) annual Generation Annual Revenue (RAG) adjustment; (ii) investments made in the upgraded power generation facilities, partially offset by: (iii) change of the CFURH fee in 2017, which is part of the fees income of the upgraded power plants and (iv) the failure to accomplish the estimated income resulting from the difference between the rate of return used in the estimation and the rate effectively used.

Generation Construction Income

7,276

11,135

-34.7

No effect on the result due to equal value in the construction expenditure, however, the variation was due to the investments made in power plants whose concessions were renewed.

Return of the Investment

14,954

0

100.0

The variation is due to the following fact: (i) the beginning of the recognition of the update of the financial asset of the renewed generation, only at the end of 2016, therefore there is no comparative value in the 1st Q 2016.

Transmission

 

 

 

 

LT Incomes Renewed by Law 12.783/2013

248,369

235,075

5.7

The variation was mainly due to: (i) RAP update in the second half of 2016 and (ii) reinforcement of lines in the transmission system.

Not renewed O&M LT

20,571

22,642

-9.1

The variation was mainly due to: (i) Annual RAP adjustment and (ii) line reinforcements in the transmission system; And (iii) unavailability of the system during the period and apportionment of anticipation, mainly in LTs: JARDIM / PENEDO and CAMAÇARI IV.

Transmission Construction Income

125,918

152,756

-17.6

No effect on the result due to the equivalent amount in construction expenses, however, the change occurred due to the reduction of works due to the Company's cash situation.

Revenue from return of investment in transmission

338,683

8,635,218

-96.1

The variation is mainly due to the first registration in 2Q16 of the RBSE financial asset according to MME Ordinance 120 of 2016 of R$ 8,618,015, while in 2Q17 there was only the recording of the remuneration on mentioned RBSE (around R$ 695,173).

Other Incomes

8,350

14,878

-43.9

The variation was mainly due to: (i) decrease of income from the provision of maintenance services.

Deductions to the Operating Revenue

-183,089

-170,120

7.6

The variation was mainly due to: (i) increase of sector taxes and charges due to increase of the revenue.

ROL

1,296,052

9,468,963

-86.3

The variation was due to the reasons explained above.

         

Operating Costs and Expenses

 

 

 

The operating costs and expenses had a decrease of 5.2% in 2Q17 compared to the 2Q16, going from R$ 910 million in 2Q16 to R$ 862 million in 2Q17, presenting the variations listed below:

         

Personnel, Material, Services and Others (PMSO) - R$ Thousand

2Q17

2Q16

Variation (%)

Analysis

Personnel

-476,303

-239,001

99.3

The variation was mainly due to: (i) Recording of provision for the retirement plan (PAE), in June 2017, in the amount of R$ 202.3 million, (ii) adjustment resulting from ACT 2016-2018 (effect of 9% of the 2016-2017 adjustment occurred after 2Q16 Due to the filing of collective dissident after the ordinary base date of the ACT and 4% of the adjustment of 2017-2018 as of May 2017) and to the increase of expenses with benefits, in the amount of R$ 21.9 million, being R$ 10.7 million related to food tickets, partially offset by (iii) a reduction of R$ 1.6 million in overtime, in accordance with PDNG 2017-2021 guidelines.

Material

-6,786

-4,828

40.6

The variation was mainly due to: (i) espenses with consumable material of R$ 0.8 million; And (ii) increase in expenses with materials and electrical systems, of R$ 0.7 million.

Services

-51,618

-53,762

-4.0

The variation was mainly due to: (i) reduction in the costs/expenditure with maintenance and preservation of equipment, amounting to R$ 2.6 million

Others

-64,804

-52,733

22.9

The variation was mainly due to: (i) increase in the recognition of expenditure with post-employment benefit, an impact of the actuarial assessment report by the end of 2016.

Donations and contributions

-1,847

-1,260

46.6

Other operating expenses

-62,957

-51,473

22.3

TOTAL PMSO

-599,511

-350,324

71.1

The variation was due to the reasons explained above.

         

Operating Costs - R$ Thousand

2Q17

2Q16

Variation (%)

Analysis

Energy Purchased for Resale

-65,770

-91,818

-28.4

The variation was mainly due to: (i) registration of 214,700 thousand of overcontracting of energy.
The distributors connected to the SIN will not be subject to the limits of overcontracting in the 3 years following the interconnection (Decree n. 7.246 / 2010), this is the case of AmD. ANEEL has already recognized in the period from May 2015 to August 2016 the amount of R $ 215 million to be considered in IRT 2017.

Fuel

0

0

0.0

 

Charges for the Use of the Electricity Grid

-146,273

-158,643

-7.8

The variation was mainly due to: (i) Reduction in the Use of the Transmission System (MUST), occurring from the second half of 2016, affecting the 1st half of 2017.

Construction Expense

-133,194

-163,891

-18.7

No effect on the result due to equal value in the construction income.

Depreciation and Amortization

-24,105

-24,960

-3.4

No relevant variation.

 

 

 

 

 

Operating Provisions

2Q17

2Q16

Variation (%)

Analysis

Operating Provisions

-8,915

-20,532

-56.6

The variation was mainly due to: (i) Provision for Contract 061 in R$ 45.2 million in 2016, without comparative in 2017, since in this half year there was an adjustment of the provision for impairment/onerous contract in the Eletrobras System. We also highlight the registration of GSF provision in the amount of R$ 50 million and civil provisions in the amount of R $ 61.0 million.

 

 

 

 

 

Financial Result - R$ Thousand

2Q17

2Q16

Variation (%)

Analysis

Financial Investments Incomes

7,711

11,679

-34.0

The variation was mainly due to: (i) reduction of financial investments for compliance with Company’s obligations.

Debt Charges

-70,574

-36,563

93.0

The variation was mainly due to: (i) new financings contracted after 2Q16 amounting to R$ 15.4 million, before Eletrobras and R$ 3.7 million with financial institutions.

Interest paid in arrears for energy sold

6,535

21,365

-69.4

The variation was mainly due to: (i) new calculation of Rio Doce Manganês debt adjustment, and (ii) adjustment of congnovit of Santana Textil before the Court of Justice of Pernambuco.

Net Exchange Variation

0

0

0.0

Not applicable

Net Monetary Correction

13,355

5,710

133.9

The variation was mainly due to: (i) adjustment of judicial deposits carried out in the period; (Ii) monetary restatement of new loans; And (iii) due to the judicial block concerning the k-factor process (without comparison in 2016).

Other Revenue/Financial Expenses

-26,449

18,896

-240.0

The variation was mainly due to: (i)Updating R & D, in the amount of R$ 19.4 million (return value provided by CEPEL); (Ii) appropriation of contractual costs of suppliers, in the amount of R$ 2.4 million; And (iii) R$ 1.8 million referring to Aneel's tax assessment notice, and (iv) R$ 1.3 million relating to the updating of amounts to be repaid.

 

 

 

 

 

         

Equity Interests (Equity) - R$ Thousand

2Q17

2Q16

Variation (%)

Analysis

Equity Interests (Equity)

25,681

12,816

100.4

The variation is mainly due to the following factors: (i) improvement in the result of generating SPEs, with a variation of 51.5% (R $ 14.3 million). A) Chapada do Piauí Holding I (R $ 3.2 million), (b) Chapada do Piauí Holding II (R $ 5.9 million) and (c) Eólica Serra das Vacas Holding (R $ 2.4 million).

         
         

Income Tax (IR) and Social Contribution on Net Income (CSLL) - R$ Thousand

2Q17

2Q16

Variation (%)

Analysis

Income Tax and CSLL

 

 

 

 

Current IR and CSLL

-31,651

-16,864

87.7

The variation was mainly due to: (i) income increase resulting from the recognition and compensation of the Existing System Basic Network (RBSE) financial asset pursuant to MME Directive 120, to be paid in a deferred manner according to the receipt.

Deferred IR and CSLL

-107,847

-2,930,894

-96.3

Revenue from Tax Incentives

25,558

0

100.0

The variation was mainly due to the fact that the Company had taxes to be paid in 2Q17, which does not happen in 2016.

 

    

 

 

 

 

 

 

17

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex II - 2Q17

Financial Information of the Subsidiaries

ELETRONORTE

        
         

Result Analysis

        
         

The Company had in 2Q17 a result 95% smaller than the one recorded in 2Q16, going from a profit of R$ 2,025 million in 2Q16 to a profit of R$ 108 million in 2Q17, mainly due to the reasons described below.

         

Operating Revenue

        
         

The Net Operating Revenue had a decrease of 69% in 2Q17, compared to the 2Q16, going from R$ 4,175 million in 2Q16 to R$ 1,296 million in 2Q17. The variations of each income account are detailed below:

         

Gross Revenue

2Q17

2Q16

Variation (%)

Analysis

Generation

 

 

 

 

Supply of energy to distribution companies

467,349

691,132

-32.4

The variation was mainly due to: (i) expiration of 2014/2016 product in the amount of 823 MW on average of energy offset by the (ii) increase of sales for energy trading companies in the amount of 459 MW on average of energy.

Supply of energy to final consumers

335,124

267,351

25.3

The variation was mainly due to: (i) strong impact by the proceeds of Albras and South 32, the two larger Company’s contracts. Such contracts have specific conditions, such as the dependence on the foreign exchange rate, price of aluminum in the international market (LME), in addition to providing for reimbursement of sect charges up to the threshold established under contract

Short Term Market (CCEE)

266,420

84,597

214.9

The variation was mainly due to: (i) expiration of ACR contract in December 2016, and part of this energy started being traded in the short term. If there is increase of the energy liquidated at CCEE. In addition to this, the average of PLD in 2016 was R$ 62.05 MW on average and R$ 95,26 MW on average in 2017.

O&M Income - Upgraded Power Plants Law 12.783/2013

4,219

3,843

9.8

The variation was mainly due to: (i) adjustment of GAG of Coaracy Nunes

Generation Construction Income

0

0

0.0

Not applicable.

Transmission

 

 

 

 

LT incomes not renewed

3,863

1,257

207.3

The variation was mainly due to: (i) takeover of Linha Verde Transmissão de Energia S.A

LT Incomes Renewed by Law 12.783/2013

119,470

109,985

8.6

The variation was mainly due to: (I) adjustment of RAP and Incorporation of strengthening.

Revenue from return of investment in transmission

253,624

3,108,740

-91.8

The variation was mainly due to: (i) recognition of financial assets of RBSE according to MME Directive 120 of 2016 of R$ 3.034 million, whereas, in 2Q17, there was only recording of compensation levied on said financial asset of about R$ 156.7 million.

Transmission Construction Income

9,882

121,643

-91.9

No effect on the result due to equal value in the expenses, although it derives from (i) smaller investments in 2016; (ii) takeover of LVTE.

Other incomes

88,126

50,752

73.6

The variation was mainly due to: (I) increase of the income from the provision of services connected to the use of grid for communication and multimedia; and (ii) provision of services under operation and maintenance.

Deductions to the Operating Revenue

-252,426

-263,771

-91.9

The variation was mainly due to: (i) charges with PIS, COFINS and PASEP.

ROL

1,295,651

4,175,529

-69.0

The variation was due to the reasons explained above.

         

Operating Costs and Expenses

 

 

The operating costs and expenses had a reduction of 4% in 2Q17 compared to the 2Q16, going from an expense of R$ 1,040 million to R$ 998 million, presenting the variations listed below:

         

PMSO

2Q17

2Q16

Variation (%)

Analysis

Personnel

-472,376

-307,098

53.8

The variation was mainly due to: (i) recording of provision for the Dismissal Incentive Plan - PAE in June/2017, amounting to R$ 125 million, (ii) an adjustment arising out of the Collective Bargaining Labor Agreement (ACT) for 2016-2018 (an effect of 9% on the 2016-2017 adjustment happened after 2Q16 owing to the filing of the collective bargaining agreement after the ordinary base date of ACT and 4% of 2017-2018 adjustment as of May 2017), which impacted only 2Q17.

Material

-7,177

-9,836

-27.0

The variation was mainly due to: (i) a number of measures to optimize the use of resources, implemented by the Company Costing Committee since 2016, such as the budgetary allocation of the non-priority expenditure and the establishment of rules that prevent the relocation between budgetary accounts.

Services

-65,480

-72,556

-9.8

The variation was mainly due to: (i) Termination of outsource third party service contract, in Dec/2016, amounting to R$ 52 million/year, partially offset by (ii) contracting of consulting of R$ 3.8 million for arranging tax liability and institutional advertising for the Company’s advertisement services.

Others

-84,743

-20,169

320.2

The variation was mainly due to: (i) reduction of legal and social liabilities that the company main develops in Tucuruí under the scope of several social programs, partially offset by the increase of other expenditure owing to: (ii) the adjustment of debt connected to the payments of taxes of financial income of the debt with Ceron (2016) amounting to about R$ 61 million. The debt adjusted at R$ 218 million (67% was paid with tax benefits from previous loss and the remainder was split in 24 installments with REFIS.

Donations and contributions

-361

-4,094

-91.2

Other operating expenses

-84,382

-16,075

424.9

TOTAL PMSO

-629,776

-409,659

54

The variation was due to the reasons explained above.

         

Operating Costs

2Q17

2Q16

Variation (%)

Analysis

Energy Purchased for Resale

-20,433

-38,921

-47.5

The variation was mainly due to: (i) reduction of the amount of purchases made in the short-term market with CCEE owing to the expiration of 2014/2016 product.

Fuel

0

0

0.0

Not applicable

Charges for the Use of the Electricity Grid

-139,010

-125,066

11.1

The variation was mainly due to: (i) increase of generation income.

Construction Expense

-9,882

-121,643

-91.9

The variation was mainly due to: (i) reduction of construction investments, as well as those resulting from the takeover of Linha Verde Transmissora de Energia Elétrica -LVTE, without effect on the result due to equal value of construction income.

Remuneration and Reimbursement Expenses

0

0

0.0

Not applicable

Depreciation and Amortization

-110,699

-117,974

-6.2

No relevant variation.

 

 

 

 

 

Operating Provisions

2Q17

2Q16

Variation (%)

Analysis

Operating Provisions

-88,435

-226,825

61.0

The variation was mainly due to: (i) adjustment TFRH Tucuruí and Curua-uma (R$ 135 million).

         

Financial Result

2Q17

2Q16

Variation (%)

Analysis

Financial Investments Incomes

26,301

21,581

21.9

The variation was mainly due to: (i) gains of financial investment with TVM.

Debt Charges

-163,806

-158,780

3.2

The variation was mainly due to: (i) payment of charges and interest rate of loan contracts of Company with Holding and financial institutions, which had a drop over the period, although there was impact on the inflation over the period.

Interest paid in arrears for energy sold

14,365

11,014

30.4

The variation was mainly due to: (i) correction of excessive delay in the revenue, especially that of Boa Vista Energia.

Net Exchange Variation

2,005

42,977

-95.3

The variation was mainly due to: (i) US currency variation.

Net Monetary Correction

6,467

5,393

19.9

The variation was mainly due to (i) adjustment of debt of CERON; (ii) and effect on the derivative instruments of the contract of ALBRÁS, (iii) increase of the company’s indebtedness by means of loan with Holding and Caixa Econômica Federal

Other Revenue/Financial Expenses

-70,284

5,249

-1439.0

The variation was mainly due to (ii) debt interest rate and charges with Holding and financial institutions.

Gains / Losses with Derivatives

-47,964

42,711

-212.3

The variation was mainly due to: (i) impact of LME on the foreign market and also reduction of dollar currency, which impact the contracts executed with ALBRAS. The gain assessed by the operation with derivatives coming from energy supply contracts over the period is R$ 68.8 million, whereas, in June 2016, the gain was R$ 121.6 million

         

Equity Interests

2Q17

2Q16

Variation (%)

Analysis

Equity Interests

24,976

-30,444

-182.0

The variation was mainly due to: (i) performance assessed by means of equity methods of the following SPES: INTESA - R$ 22 Million; Energética Àguas da Pedra - R$ 12 million; Norte Brasil -R$ 28 million and Manaus Transmissora - R$ 13 Million.

         

Income Tax and CSLL

2Q17

2Q16

Variation (%)

Analysis

Current IR and CSLL

-23,444

-129,074

-81.8

The variation was mainly due to: (i) Recognitio of the Existing System Basic Network (RBSE).

Deferred IR and CSLL

22,732

-916,893

-102.5

Revenue from Tax Incentives

18,740

-3,564

-625.8

The variation was mainly due to: (i) smaller utilization of tax incentive credits.

 

18

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex II - 2Q17

Financial Information of the Subsidiaries

FURNAS

        
         

Result Analysis

         

The Company had in 2Q17 a result 94% smaller than the one recorded in 2Q16, going from a profit of R$ 8,369 million in 2Q16 to a profit of R$ 480 million in 2Q17, mainly due to the reasons described below.

         

Operating Revenue - Generation and Transmission Companies

 

        

The Net Operating Revenue had a decrease of 84% in 2Q17, compared to the 2Q16, going from R$ 14,106 million in 2Q16 to R$ 2,256 million in 2Q17. The variations of each income account are detailed below:

         

Gross Revenue

2Q17

2Q16

Variation (%)

Analysis

Generation

 

 

 

 

Supply of energy to distribution companies

989,358

836,243

18.3

The variation was mainly due to: (i) variation of the portfolio of purchase and sale of Energy; (ii) Expiration of 2009/2016 Product in December 2016; (iii) Returns of Energy contracted from CCEARs of products of Existing Energy, under the scope of the Surplus and Deficit Compensation Mechanism - MCSD, owing to the migration of free consumers and MCSD 4%, happened in October/2016, causing strong impacts as of 2017; (iv) New Contracts under the Environment of Free Contracting with variation of average price, owing to the market scenarios; (v) Updating of prices of contracts by IPCA.

Supply

48,292

-

100.0

The variation was mainly due to: (i) execution of new energy contracts with final consumers as of November 2016; (ii) Auctions of Itumbiara Power Plant, in accordance with Law 13.182/2015, which yielded new revenue from Supply of energy. The contracts of Itumbiara HPP are recorded as Supply of R$ 40 million (net of ICMS) for 2Q17.

Short Term Market (CCEE)

13,037

58,139

-77.6

The variation was mainly due to: (i) payments of Jan/2016 to May/2016 connected to the Redefinition of the Hydrological Risk, calculated according to the methodology approved by ANEEL by means of Order n. 758/2016. Such payments have not been made in 2017, (ii) the differences in the portfolio of contracts, (iii) the variation of the amount of energy generated, as well as the consequent impact on the result on the Energy Relocation Mechanism (MRE), partially offset by (iv) the variations of the values of PLD over the periods of Apr/2016 to Jun/2016 were such that, the average PLD was R$ 62.37/MWh, whereas, over the same period of 2017, it was R$ 303.75/MWh

O&M Income - Upgraded Power Plants Law 12.783/2013

209,977

203,457

3.2

The variation was mainly due to: (i) adjustment provided for under the contracts of fees of renewed power plants.

Generation Construction Income

6,532

7,088

-7.8

No effect on the result, due to the equal construction expense, however, the variation was mainly due to: (i) the fluctuation of investments made in HPPs Corumbá, Furnas, Funil, Marimbondo, Porto Colômbia and LCB de Carvalho.

Transmission

 

 

 

  

LT incomes not renewed

9,870

8,701

13.4

The variation is mainly due to: (i) readjustment of the RAPs of the other contracts and (ii) accounting reclassification to O&M Revenues of the renewes transmission

O&M LT renewed by Law 12.783/2013

314,889

283,812

10.9

The variation was mainly due to: (i) variation of the CT 062.2001 contract amounting to R$ 30.9 million

Income from return of investment in transmission

780,537

12,750,400

-93.9

The variation is mainly due: (I) the first registration, in 2Q16, of the financial asset of RBSE, in accordance with MME Directive 120 of 2016 of R$ 12,710 million, whereas, in 2Q17, there was only a recording of compensation levied on said financial asset of R$ 736.2 million, and; (ii) other contracts amounting to R$ 5.1 million.

Transmission Construction Income

51,000

171,809

-70.3

No effect in the result due to equal expense, however, it results from (i) the increase of the investments in the Ribeiro Gonçalves Balsas concession contract.

Other incomes

73,726

9,419

682.7

The variation was mainly due to: (i) increase in the Income from the Provision of Services, chiefly the amount of R$ 65.4 million with Eletrobras Participações connected to the use of optical fiber wiring (contract with Eletronet of 1999).

Deductions to the Operating Revenue

- 241,188

- 222,499

8.4

The variation was mainly due to: (i) To the increase of ICMS in R$ 8.3 million and PIS / COFINS in R$ 23.6 million

ROL

2,256,030

14,106,569

-84

The variation was due to the reasons explained above.

         

Operating Costs and Expenses

 

The operating costs and expenses had an increase of 1.0% in 2Q17 compared to the 2Q16, going from R$ 1,201 million to R$ 1,213 million, presenting the variations listed below:

         

PMSO

2Q17

2Q16

Variation (%)

Analysis

Personnel

-533,029

-271,753

96.1

The variation was mainly due to: The variation was mainly due to: (i) recording of provision for the Retirement Plan - PAE in June/2017, amounting to R$ 211.8 million, (ii) an adjustment arising out of the Collective Bargaining Labor Agreement (ACT) for 2016-2018 (an effect of 9% on the 2016-2017 adjustment happened after 2Q16 owing to the filing of the collective bargaining agreement after the ordinary base date of ACT and 4% of 2017-2018 adjustment whcich affected the 2Q17

Material

-6,651

-10,126

-34.3

The variation was mainly due to: (i) The material expenditure reduced mainly due to the variation of costs with several materials, as well as reduction of spending, aiming to decrease expenditure.

Services

-220,421

-201,260

9.5

The variation was mainly due to: (i) increase of outsourced third party services, with Engeneering company

Others

-142,266

-74,318

91.4


The variation was mainly due to: (i) increase in the following lines: Insurance R$ 1.5 million, Indemnity, Loss and damages R $ 25 million (highlighting in 2Q17 the lawsuit against Ampla Energia and Serviços S/A in the amount of R $ 43.3 million, losses on deactivation and disposal R $ 22.2 million (highlighting the deactivation of 02 autotransformers of the Substation of Samambaia in the amount of R $ 17.7 million) and a reduction in the recovery of Expenses of R $ 8 million.

Donations and contributions

-20,530

-7,239

183.6

Other operating expenses

-121,736

-67,079

81.5

TOTAL PMSO

-902,367

-557,457

62

The variation was due to the reasons explained above.

         

Operating Costs

2Q17

2Q16

Variation (%)

Analysis

Energy Purchased for Resale

-197,835

-140,002

41.3

The variation was mainly due to: (i) Reduction of power generation via the Santa Cruz Thermoelectric Power Plant.

Fuel

-75,824

-93,948

-19.3

The variation was mainly due to: (i) reduction of the generation of energy by means of Santa Cruz Thermal Power Plant.

Charges for the Use of the Electricity Grid

-130,350

-117,865

10.6

The variation was mainly due to: (i) adjustment estimated for the transmission contracts.

Construction Expense

-57,532

-178,897

-67.8

No effect on the result due to equal value in the construction income.

Remuneration and Reimbursement Expenses (Use of water resources)

0

0

0.0

Not applicable

Depreciation and Amortization

-69,432

-68,813

0.9

No relevant variation.

 

 

 

 

 

Operating Provisions

2Q17

2Q16

Variation (%)

Analysis

 

219,624

- 44,263

- 596.18

The variation was mainly due to: (i) reduction of the balance of PCLD in R$ 3.2 million, (ii) Reversal of (Tax, Labor and Civil) Contingencies, R$ 157.2 million, (iii) Onerous Contract, R$ 109.5 million (Furnas, R$ 52 million, and SPEs Brasil Ventos, R$ 161.4 million, (iv) reversal of onerous contract as a result of suspension of energy contract of Famosa 3, Serra do Mel and Acarau complexes) and (v) R$ 298 million connected to the reversal of provision for loss with Investments.

         

Financial Result

2Q17

2Q16

Variation (%)

Analysis

Financial Investments Incomes

8,196

19,759

-58.5

The variation was mainly due to: (i) Decrease in the financial investments in the period.

Revenue from Financing and Loans

33,146

16,104

105.8

The variation was mainly due to: (i) due to the reclassification of the account balance from arrears to financing and loan income, in the amount of R $ 16.1 million.

Debt Charges

-253,538

-257,254

-1.4

The variation was mainly due to: (i) reduction in debt charges, but without significant variation.

Interest paid in arrears for energy sold

-13,492

1,914

-804.9

The variation was mainly due to: (i) Transfer from the account balance to Revenues from financing and loans in the amount of R$ 16.1 million.

Net Exchange Variation

-18,170

41,053

-144.3

The variation was mainly due to: (i) Exchange rate depreciation on loans and financing obtained in long-term foreign currency with the IDB (dollar) and Eximbank (Yen), in the amount of R $ -62.2 million

Net Monetary Correction

-37,913

-62,896

-39.7

The variation is mainly due to: (i) the passive monetary correction had a reduction in the VM expense on the long-term debt principal, amounting to R$ 31 million as a result of the fluctuation of the interest rates (SELIC, IPCA, and TJLP) and, in the of VM on other PELP owing to the change of VM’s booking of assignment of credit, given that, in 2016, the year had the value of 55.1 million fully entered, and, in 2017, the value of R$ 19.3 million was entered in Advanced Expense - Assets and was deferred to the result of R$ 604 per month, which has triggered a reduction of R$ 54 million in the account movements, partially offset (ii) by the reduction of the active monetary correction on the Electric Power Refinancing, amounting to R$ 31 million, in addition to the decrease of the monetary adjustment w/ negative balance of IRPJ/CSSL amounting to R$ 16.7 million.

Other Revenue/Financial Expenses

-10,108

-34,192

-70.4

The variation was mainly due to: (i) Increase in interest income by R$ 1 million, (ii) and increase in Other Revenues - Contractual Fines by R$ 4.3 million; (Ii) Financial expenses with the reduction of the Selic interest rate increase of undivided dividends of R$ 14.5 million.

Gains / Losses with Derivatives

0

0

 

Not applicable

         

Equity Interests (Equity)

2Q17

2Q16

Variation (%)

Analysis

 

7,609

57,988

-86.9

The variation was mainly due to: (i) capitalization of new tangible assets, with emphasis on equipment and buildings Chapecoense R$ 11,6 milhões, Mata de Santa Genebra R$ 7,0 milhões, Serra do Facão Energia R$ 6,3 milhões e MGE Transmissão R$ 4,8 milhões.

         

Income Tax and CSLL

2Q17

2Q16

Variation (%)

Analysis

Current IR and CSLL

-9,409

1,725

-645.4

The variation was mainly due to: (i) the net result (except for the monetary correction of RBSE), in 2017, it was smaller than that of 2016, as well as the variation of provisions in 2017. In the year of 2017, there is a deferral levied only on the monetary adjustment of RBSE, given that, in the valance of 2016, there is recording of deferral covering the total revenue of RBSE, i.e., the initial value plus the adjustments of the year.

Deferred IR and CSLL

-252,636

-4,319,972

-94.2

Revenue from Tax Incentives

0

0

0.0

Not applicable.

 

19

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex II - 2Q17

Financial Information of the Subsidiaries

ELETROSUL

        
         

Result Analysis

        
         

The Company had in 2Q17 a result 72% smaller than the one recorded in 2Q16, going from a profit of R$ 930 million in 2Q16 to a profit of R$ 262 million in 2Q17, mainly due to the reasons described below.

         

Operating Revenue

         

The Net Operating Revenue had a decrease of 72% in 2Q17, compared to the 2Q16, going from R$ 1,861 million in 2Q16 to R$ 530 million in 2Q17. The variations of each income account are detailed below:

         

Gross Revenue

2Q17

2Q16

Variation (%)

Analysis

Generation

 

 

 

 

Supply of energy to distribution companies

235,350

176,558

33.3

The variation was mainly due to: (i) adjustment of prices; (ii) variation of prices in ACL (PCHs and part of the energy generated by wind power plants resold in ACL); (iii) new energy purchase contracts, as of April 2017, executed with SPE Teles Pires; (iv) as of 2017, the wind power plants Hermenegildo I, II, III and Chuí IX suspended the contract of ACRs by means of the New Energy Surplus and Deficit Compensation Mechanism, and the energy by Eletrosul was also no longer contracted, and mainly sold in ACL, by means of short and long term auctions.

Supply

4,917

5,766

-14.7

The variation was mainly due to: (i) variation of price in long term contracts executed in October 2015, in the ACL environment, with specific prices for each year of supply.

Short Term Market (CCEE)

10,565

836

1,163.8

The variation was mainly due to: (i) increase of PLD; e (ii) variation of the volume of energy liquidated in CCEE (MRE and liquidation of PLD)

Generation Construction Income

0

0

0.0

Not applicable

Transmission

 

 

 

 

RAPs LT not renewed

29,811

25,069

18.9

The variation was mainly due to: (i) adjustments in the prices of RAP; and (ii) installment of adjustment for the period, used to redefine positive or negative adjustments in RAP under each concession contract, such as, for instance, deviation of estimate.

O&M LT renewed by Law 12.783/2013

154,177

158,213

-2.6

The variation was mainly due to: (i) adjustments in the pro-rating of the system performed by ONS coming from the deficit and surplus analysis of the system charges; and (ii) part of adjustment for the period, used to define positive or negative adjustments in RAP under each concession contract, such as, for instance, deviation of estimate.

Income from return of investment in transmission

121,326

1,498,355

-91.9

The variation was mainly due to: (i) initial recording, in 2Q16, of the compensation of the financial asset of RBSE, in accordance with Directive no. 120, dated April 20, 2016, of the Ministry of Mines and Energy (R$ 1,447.4 million), whereas in 2Q17, only the compensation levied on the financial asset receivable was recorded (about R$ 67,058 million) and (ii) inflation over the period.

Transmission Construction Income

21,469

38,668

-44.5

No effect for the result, due to consideration of the construction expense, in equal value. The variation was mainly due to: (i) the failure to account, in 2017, for the construction revenue linked to the Concession Agreement 001/2015 regarding the deployment of the enterprise of Lot A - ANEEL Auction 004/2014, being the Company in negotiation phase for partner in the execution of the contract.

Other Incomes

11,777

5,721

105.9

The variation was mainly due to the increase in the provision of services to third parties, with emphasis on the services of operation and maintenance of transmission lines related to binational enterprise (Brazil-Uruguay Interconnection).

Deductions to the Operating Revenue

-59,276

-47,905

23.7

The variation was mainly due to revenue increase.

ROL

530,116

1,861,281

-72

The variation was mainly due to the reasons explained above.

         

Operating Costs and Expenses

The operating costs and expenses had an increase of 9.2% in 2Q17 compared to the 2Q16, going from R$ 269 million to R$ 244 million, presenting the variations listed below:

         

PMSO

2Q17

2Q16

Variation (%)

Analysis

Personnel

-163,538

-99,607

64.2

The variation was mainly due to: (i) recording of provision for the Dismissal Incentive Plan - PAE in June/2017, amounting to R$ 51 million, which refers to 155 hirings, (ii) an adjustment arising out of the Collective Bargaining Labor Agreement (ACT) for 2016-2018 (an effect of 9% on the 2016-2017 adjustment happened after 2Q16 owing to the filing of the collective bargaining agreement after the ordinary base date of ACT and 4% of 2017-2018 adjustment as of May 2017), in addition to (iii) reduction of overtime made as a way to reduce costs, as established in PDNG 2017-2021.

Material

-2,158

-2,359

-8.5

The variation was mainly due to: (i) decrease, in 2017, of the material expenses related to the operation and maintenance of the electric system, as a measure to reduce costs provided for in PDNG 2017-2021.

Services

-26,264

-29,921

-12.2

The variation was mainly due to: (i) decrease, in 2017, of the expenses with third party services, including institutional advertisement, as a measure to reduce costs provided for in PDNG 2017-2021.

Others

-7,403

-11,543

-35.9

The variation was mainly due to: (i) liquidation, in 2017, of the contributions to CEPEL with funds of P&D.

Donations and contributions

0

0

0.0

Other operating expenses

-7,403

-11,543

-35.9

TOTAL PMSO

-199,363

-143,430

39

The variation was mainly due to the reasons explained above.

         

Operating Costs

2Q17

2Q16

Variation (%)

Analysis

Energy Purchased for Resale

-72,602

-58,868

23.3

The variation was mainly due to: (i) amounts of additional energy purchased by HPP Teles Pires, arising out of the suspension of contract of energy sold by the same in ACR.

Fuel

0

0

0.0

Not applicable

Charges for the Use of the Electricity Grid

-6,684

-6,531

2.3

The variation was mainly due to: (i) adjustment of the TUST and TUSD.

Construction Expense

-21,469

-38,668

-44.5

No effect on the result due to equal value in the construction income.

Depreciation and Amortization

-45,061

-44,478

1.3

Os valores permaneceram estáveis.

 

 

 

 

 

Operating Provisions

2Q17

2Q16

Variation (%)

Analysis

 

212,502

-6,664

-3,288.8

The variation was mainly due to: (i) reversals of impairments of Wind Power Plants Hermenegildo I, II, III and Chuí IX, amounting to R$ 217 million.

         

Financial Result

2Q17

2Q16

Variation (%)

Analysis

Financial Investments Incomes

13,062

9,857

32.5

The variation was mainly due to: (i) addition, in 2017, of the balance of financial investments, especially arising out of the raising of funds performed in January 2017, via the Fund of Investments in Credit Rights - FIDC.

Debt Charges

-126,462

-125,019

1.2

The variation was mainly due to the higher volume of charges of loans and financings, arising out of the variation of their amount.

Interest Paid in Arrears

0

0

0.0

Not applicable.

Net Exchange Variation

-22,813

30,361

-175.1

The variation was mainly due to: (i) Euro has risen and impacted contracts of transfer of funds signed with Eletrobras, arising from contracts with KFW, whose funds were used for the construction of PCHs.

Net Monetary Correction

-28,782

3,078

-1035.1

The variation was mainly due to: (i) decrease of the adjustment of credits of energy renegotiated, arising out of Law 8727/93, connected to a negative IGPM happened over the second quarter of 2017; and (i) decrease of inflation indices.

Other Revenue/Financial Expenses

21,396

14,641

46.1

The variation was mainly due to: i) increase of the debt balance of securities receivable concerning 8.727/93, owing to the fact that the monthly amount received was not enough to amortize the charges generated; and ii) decrease of the financial adjustment of the amounts receivable from Eletronorte, a result of the negotiation of assets, in connection with the amortization of credits. The variation of this expense was mainly due to: (i) recording in 2016 of IOF connected to loans.

         
         

Equity Interests (Equity)

2Q17

2016

Variation (%)

Analysis

 

93,778

-54,406

272.4

The variation was mainly due to: (i) positive result assessed, in 2017, by invested companies Livramento Holding, Chuí Holding and Santa Vitória Palmar Holding. After the option for MCSD (suspension of contract of CCEARs), invested companies started selling energy in bilateral contracts and/or liquidating in CCEE at prices higher than the contracts executed with the distribution companies under ACR. Such fact led to a higher volume of income, and allowed reversal of impairment thereon.

         

Income Tax and CSLL

2Q17

2Q16

Variation (%)

Analysis

Current IR and CSLL

556

2,735

-79.7

The variation was mainly due to: (i) increase, in 2017, of the result from service, mainly influenced by the increase of net revenue. For the purposes of calculation of current taxes, the financial revenue of RBSE is excluded.

Deferred IR and CSLL

-82,660

-511,715

-83.8

The variation was mainly due to: (i) reversals, in 2017, of the impairments of Wind Power Plants Hermenegildo I, II, II and Chuí IX; (ii) recording, in June 2016, of the initial amount of the financial revenue of RBSE.

Revenue from Tax Incentives

0

0

0.0

Not applicable.

 

20

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex II - 2Q17

Financial Information of the Subsidiaries

ELETRONUCLEAR

        
         

Result Analysis

        
         

The Company had in 2Q17 a result 101% higher than the one recorded in 2Q16, going from a loss of R$ 4.054 million in 2Q16 to an increase of R$ 42 million in 2Q17, mainly due to the reasons described below.

         

Operating Revenue

         

The Net Operating Revenue had an increase of 8.8% in 2Q17, compared to the 2Q16, going from R$ 639 million in 2Q16 to R$ 695 million in 2Q17. The variations of each income account are detailed below:

         

Gross Revenue

2Q17

2Q16

Variation (%)

Analysis

Generation

 

 

 

 

Supply of energy to distribution companies

792,845

728,883

8.8

The variation is due to the following reasons: (i) updating of the fixed revenue established by ANEEL for the 2017 fiscal year, through Aneel Resolution 2,193 / 16, for the Angra 1 and 2 plants; And (ii) the positive balance of the variable portion referring to the electric power generated / supplied estimated for 2017.

Deductions to the Operating Revenue

-97,498

-89,687

8.7

The variation is due to the following reasons: (i) taxation of 9.25% of PIS and COFINS as a result of the increase in Gross Operating Revenue; (Ii) increased contributions from consumer charges

ROL

695,347

639,196

8.8

The variation was due to the reasons explained above.

         

Operating Costs and Expenses

The operating costs and expenses had an increase of 86.7% in 2Q17 compared to the 2Q16, going from R$ 4.537 million to R$ 603 million, presenting the variations listed below:

         

PMSO

2Q17

2Q16

Variation (%)

Analysis

Personnel

-226,422

-117,149

93.3

The variation was mainly due to: (i) recording of provision for the Dismissal Incentive Plan - PAE in June/2017, amounting to R$ 71.6 million, (ii) an adjustment arising out of the Collective Bargaining Labor Agreement (ACT) for 2016-2018 (an effect of 9% on the 2016-2017 adjustment happened after 2Q16 owing to the filing of the collective bargaining agreement after the ordinary base date of ACT and 4% of 2017-2018 adjustment as of May 2017)

Material

-9,988

-10,444

-4.4

The variation was mainly due to the variations resulting from the need for maintenance material, which varies every year depending on the material needed and the value of the material available in store.

Services

-53,457

-62,681

-14.7

The variation was mainly due to: (i) Reduction of services provided by contractors; (Ii) reduction of technical and other consultancies.

Others

-28,695

-24,277

18.2

The variation was mainly due to: (i) taxes line item that, in 2017, presented a value 50% higher than that of 2016 and; (Ii) higher leases 14%.

Donations and contributions

0

0

0.0

Other operating expenses

-28,695

-24,277

18.2

TOTAL PMSO

-318,562

-214,551

48.5

The variation was due to the reasons explained above.

         

Operating Costs

2Q17

2Q16

Variation (%)

Analysis

Energy Purchased for Resale

0

0

0.0

Not applicable

Fuel

-103,343

-96,117

7.5

The variation was mainly due to: (i) price adjustment of nuclear fuel contracts consumed in the production of enegria.

Charges for the Use of the Electricity Grid

-24,627

-21,390

15.1

The variation was mainly due to: (i) transmission contratcs adjustments.

Construction Expense

0

0

0.0

Not applicable

Depreciation and Amortization

-98,960

-98,999

0.0

The variation was not relevant in the period.

 

 

 

 

 

Operating Provisions

2Q17

2Q16

Variation (%)

Analysis

 

-57,898

-4,106,495

-98.6

The variation was mainly due to: (i)Provision for Impairment and Onerous Contract registered in June 2016 without correspondent in June 2017.

         

Financial Result

2Q17

2Q16

Variation (%)

Analysis

Financial Investments Incomes

1,759

507

246.9

The variation was mainly due to: (i) the increase of financial investments due to the temporary availability of funds from the cash flow in 2017, which exceeded the amount available in 2016.

Debt Charges

-20,281

-25,048

-19.0

The variation was mainly due to: (i) Reduction of the level of indebtedness

Interest Paid in Arrears

0

0

0.0

Not applicable

Net Exchange Variation

-14,979

-16,580

9.7

The variation was mainly due to: (i) Reduction of the suppliers in foreign currency.

Other Revenue/Financial Expenses

10,125

-63,139

116.0

The variation was mainly due to: (i) variation of the value of the dollar in the period that affected the output of the decommissioning fund of Banco do Brasil, which has the dollar as the indexer.

 

21

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex II - 2Q17

Financial Information of the Subsidiaries

CGTEE

        
         

Result Analysis

        
         

The Company had in 2Q17 a result 712% higher than the one recorded in 2Q16, going from a loss of R$ 33 million in 2Q16 to a loss of R$ 270 million in 2Q17, mainly due to the reasons described below.

         

Operating Revenue - Generation and Transmission Companies

         

The Net Operating Revenue had a decrease of 58% in 2Q17, compared to the 2Q16, going from R$ 230 million in 2Q16 to R$ 97 million in 2Q17. The variations of each income account are detailed below:

         

Gross Revenue

2Q17

2Q16

Variation (%)

Analysis

Generation

 

 

 

 

Supply of energy to distribution companies

110,408

243,218

-54.6

The variation was mainly due to: (i) Estimated revenue in CCEE financial settlements, which in 2Q17 is lower than 2Q16, due to a greater number of stops for maintenance of Phase C and exit of the Presidente Medici Power Plant from 1Q17.

Other Incomes

397

986

-60

The variation was mainly due to: (i) Reduction in sales of ash.

Deductions to the Operating Revenue

-14,033

-13,984

0

The variation was mainly due to: (i) RGR provision in 2017.

ROL

96,772

230,220

-58

The variation was due to the reasons explained above.

         

Operating Costs and Expenses

The operating costs and expenses had an increase of 1.4% in 2Q17 compared to the 2Q16, going from R$ 190 million to R$ 193 million, presenting the variations listed below:

         

PMSO

2Q17

2Q16

Variation (%)

Analysis

Personnel

-77,985

-28,292

175.6

The variation was mainly due to: (i) Record of provision for the Retirement Plan - PAE and PDVE (Extraordinay Reteirement Plan) in June / 2017, in the amount of R$ 46 million; (Ii) adjustment resulting from ACT 2016-2018 (effect of 9% of the 2016-2017 adjustment occurred after 2Q16 due to the filing of collective bargaining agreement after the ordinary base date of the ACT and 4% adjustment of 2017-2018 as of May 2017)million connected to overtime, according to PDNG 2017-2021 guidelines.

Material

-18,000

-21,238

-15.2

The variation is mainly due to the following reason: (i) reduction in the value of the lime contracts used to control pollutants in the air emissions of the Candiota III - Phase C UTE.

Services

-13,587

-12,858

5.7

The variation was mainly due to: (i) Extra repairs required at the stop of UTE Candiota III - Phase C in 2Q17.

Others

-10,665

-17,733

-39.9

The variation was mainly due to: (i) Less volume of workers 'and outsourced workers' compensation payments.

Donations and contributions

0

0

0

Other operating expenses

-10,665

-17,733

-40

TOTAL PMSO

-120,237

-80,121

50.1

 

         

Operating Costs

2Q17

2Q16

Variation (%)

Analysis

Energy Purchased for Resale

-52,118

-33,273

56.6

The variation is mainly due to the following reason: (i) the purchase contracts with Eletronorte increased by 10% between quarters, reflecting the increase in the price, without changes in the quantities purchased. In this expense group, reversals of provisions for reimbursements to customer distributors were recorded in 2Q16, contributing to the increase in expenses between the periods.

Fuel

-34,675

-39,578

-11.7

The variation was mainly due to: (i) reduction of the amounts of coal purchased to be used in the Thermoelectric Plant Candiota III (Phase C) and (ii) cancellation of the purchase of coal for the Thermoelectric Plant Presidente Médici (Phases A and B) as from 2017.

(-) Recovery of CCC Expenses

25,795

29,522

Charges for the Use of the Electricity Grid

-11,540

-10,310

12

The variation was mainly due to: (i) the reflection of the adjustment of fees

Construction Expense

0

0

0

Not applicable

Depreciation and Amortization

-13,186

-18,142

-27

The variation was mainly due to: (i) Phase B of the Presidente Médici plant with effect in 2Q17 and retroactive in 1Q17 (reversing the assets as of March 1, 2017).

Operating Provisions

2Q17

2Q16

Variation (%)

Analysis

 

-36,364

182

-20,080.2

The variation was mainly due to: (i) Reversal of labor provisions in 2Q16.

         

Financial Result

2Q17

2Q16

Variation (%)

Analysis

Financial Investments Incomes

687

1,026

-33.0

The variation was mainly due to: (i) Reduction in the available balance of financial investments in 2Q17.

Debt Charges

-123,122

-109,039

12.9

The variation was mainly due to: (i) increased balance of the loans with the Holding

Interest Paid in Arrears

0

0

0.0

Not applicable

Net Exchange Variation

0

0

0.0

Not applicable

Net Monetary Correction

0

0

0.0

Not applicable

Other Revenue/Financial Expenses

233

-1,188

119.6

The variation was mainly due to: (i) Reduction in lime transporters' indemnities in 2Q17.

 

22

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex II - 2Q17

Financial Information of the Subsidiaries

AMAZONAS GT

        
         

Result Analysis

         

The Company had in 2Q17 a result 103% higher than the one recorded in 2Q16, going from a loss of R$ 102 million in 2Q16 to a loss of R$ 3 million in 2Q17, mainly due to the reasons described below.

         

Operating Revenue - Generation and Transmission Companies

         

The Net Operating Revenue had an increase of 196% in 2Q17, compared to the 2Q16, going from R$ 90 million in 2Q16 to R$ 268 million in 2Q17. The variations of each income account are detailed below:

         

Gross Revenue

2Q17

2Q16

Variation (%)

Analysis

Generation

 

 

 

 

Supply of energy to distribution companies

144,893

153,606

-5.7

The variation is mainly due to the following reason: (i) in 2017, thermal plants generated a lower amount of energy contracted due to maintenance problems, especially by Aparecida and Mauá Block 3.

Supply

0

0

0.0

Not applicable

Short Term Market (CCEE)

0

0

0.0

Not applicable

Generation Construction Income

0

0

0.0

Not applicable

Transmission

 

 

0.0

Not applicable

RAPs LT not renewed

0

0

0.0

Not applicable

O&M LT renewed by Law 12.783/2013

0

0

0.0

Not applicable

Income from return of investment in transmission

193,499

0

0.0

Not applicable

Transmission Construction Income

0

0

0.0

Not applicable

Other Incomes

0

0

0.0

Not applicable

Deductions to the Operating Revenue

-70,721

-63,094

12.1

The variation was mainly due to: (i) In the 2Q16, the amount of R & D for the period 2015/2016 was recorded.

ROL

267,671

90,512

195.73

The variation was due to the reasons explained above.

         

Operating Costs and Expenses

The operating costs and expenses had an increase of 53.8% in 2Q17 compared to the 2Q16, going from R$ 136 million to R$ 63 million, presenting the variations listed below:

         

PMSO

2Q17

2Q16

Variation (%)

Analysis

Personnel

-33,893

-30,603

10.8

The variation was mainly due to: (i) The variation is mainly due to the following factors: (i) adjustment resulting from ACT 2016-2018 (effect of 9% of the 2016-2017 adjustment, occurred after 2Q16 due to the filing of collective bargaining agreement after the ordinary base date of the ACT and 4% adjustment from 2017-2018 as of May 2017).

Material

-20

-2,632

-99.2

The variation was mainly due to: (i) Plant maintenance in a smaller proportion than in the same period of 2016.

Services

-7,695

-8,923

-13.8

The variation was mainly due to: in 2016, the amounts were recorded via the Reimbursement Expenditure Order - ODR, due to the unbundling process; However, some expenses were not recorded in the accrual period. By 2017, some contracts, such as the surveillance service, have already been contracted directly by AmGT, thus, the registrations took place in the jurisdiction.

Others

-178,077

-195,861

-9.1

The variation is mainly due to the following reason: (i) in the 2Q17 there were only 2 months of the generator rental companies (May and June), since before that, they were in the performance test process with the ONS. In 2016, this expense was recorded in the three months of the 2Q16

Donations and contributions

0

0

0.0

Other operating expenses

-178,077

-195,861

-9.1

TOTAL PMSO

-219,685

-238,019

-7.7

 

 

 

 

 

 

Operating Costs

2Q17

2Q16

Variation (%)

Analysis

Energy Purchased for Resale

-37,331

0

100.0

The variation was mainly due to: (i) amount of energy that the Company purchased in the Short Term Market, in the 2Q17, due to the cut in gas supply at the Aparecida plant.

Fuel

141,416

156,112

-9.4

The variation was mainly due to: (i) In 1TRI / 16, there were still amounts recorded under this item. However, as of April / 16, with the publication of Ordinances MME no. 015 and 179/2016, it was incumbent on the Lessors to purchase fuel oil. Thus, the Company was relieved to buy fuel as of that month.

Construction Expense

0

0

  

Not applicable

Remuneration and Reimbursement Expenses (Use of water resources)

0

0

0.0

Not applicable

Depreciation and Amortization

-15,643

-15,833

-1.2

No relevant variation.

 

 

 

 

 

Operating Provisions

2Q17

2Q16

Variation (%)

Analysis

 

-234

796

-129.4

A variação se deve, principalmente, ao seguinte motivo: (i) In 2Q16 there were reversals of provisions for contingencies of R$ 796 thousand; (Ii) In 2Q17, there was a reversal of contingency of R$ 435 thousand offset, however, by (iii) provision of assets that were not unitized and are in property, plant and equipment in progress but should already be in service, Are not being depreciated, in the amount of R$ 0.6 million.

 

 

 

 

 

Financial Result

2Q17

2Q16

Variation (%)

Analysis

Financial Investments Incomes

1,376

4,988

-72.4

The variation was mainly due to: (i) redemption of financial investments for expenses.

Debt Charges

-58,836

-66,864

-12.0

The variation was mainly due to: (i) new loan contracts signed with the holding Eletrobras, after the 2Q16.

Interest Paid in Arrears

0

0

0.0

Not applicable

Net Exchange Variation

0

0

0.0

Not applicable

Net Monetary Correction

-1,559

-5,092

-69.4

The variation was mainly due to: (i) In 2Q16, the amounts of judicial deposits arising from the net assets were updated; (Ii) reduction in monetary restatement in 2017 due to the variation of the indices; And (ii) reduction in the monetary restatement of the El Paso Rio Negro and Amazonas cases, linked to the IPCA.

Other Revenue/Financial Expenses

-2,454

-10,200

-75.9

The variation is mainly due to the following reason: (i) receipt of a fine and interest from Amazonas GT regarding the payment in arrears, in the amount of R$ 6 million.

         

Equity Interests (Equity)

2Q17

2Q16

Variation (%)

Analysis

 

0

0

0.0

Not applicable

 

23

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex II - 2Q17

Financial Information of the Subsidiaries

ELETROPAR

        
         

Result Analysis

         

The Company had in 2Q17 a result 200% higher than the one recorded in 2Q16, going from a loss of R$ 1 million in 2Q16 to a loss of R$ 2 million in 2Q17, mainly due to the reasons described below.

         

Operating Costs and Expenses

The operating costs and expenses had an increase of 5% in 2Q17 compared to the 2Q16, going from R$ 1.69 million to R$ 1.77 million, presenting the variations listed below:

         

Personnel, Material, Services and Others (PMSO) - R$ Thousand

2Q17

2Q16

Variation (%)

Analysis

Personnel

-844

-787

7.2

The variation was mainly due to: (i) Adjustment resulting from ACT 2016-2018 (effect of 9% of the 2016-2017 adjustment, which occurred after 2Q16, due to the filing of collective bargaining agreement after the ordinary ACT base date and a 4% adjustment of 2017-2018 as of May 2017.

Material

-7

-21

-66.7

The variation was mainly due to: (i) lower demand for materials in the period.

Services

-196

-208

-5.8

The variation was mainly due to: (i) lower expenses with escritutral shares services.

Others

-638

-628

1.6

The variation was mainly due to: (i) expenses with legal advertising (ex.: financial statements, notice of OGM) and rent increase.

Donations and contributions

0

0

0.0

Other operating expenses

-638

-628

1.6

TOTAL PMSO

-1,685

-1,644

2.5

The variation was due to the reasons explained above.

 

 

 

 

 

Operating Provisions - R$ Thousand

2Q17

2Q16

Variation (%)

Analysis

 

0

-474

-100

The variation was mainly due to: (i) Recognition, in the2Q17 of loss in the subscription of CTEEP shares, in the amount of $ 474 thousand.

 

 

 

 

 

Financial Result - R$ Thousand

2Q17

2Q16

Variation (%)

Analysis

Financial Investments Incomes

1,343

2,014

-33.3

The variation was mainly due to: (i) Reduction due to the decrease in interest taxand the lower value applied than in the previous period.

Debt Charges

0

0

0.0

Not applicable

Interest Paid in Arrears

0

0

0.0

Not applicable

Net Exchange Variation

0

0

0.0

Not applicable

Net Monetary Correction

0

0

0.0

Not applicable

Other Revenue/Financial Expenses

-215

-507

57.6

A variação se deve principalmente aos seguintes motivos: (i) Increase by opening the accounts, separating the financial income from application, interest income, fine and monetary correction; And (ii) monetary restatement on the amounts payable to the assignors was negative, due to negative IGP-M in the period.

Remuneration of Indemnities of the 1st tranche of Law 12.783/2013

 

 

0.0

0.0

 

 

 

 

 

Equity Interests (Equity) - R$ Thousand

2Q17

2Q16

Variation (%)

Analysis

 

3,259

2,292

42.2

The variation was mainly due to: (i) Equivalence equity of the investee CTEEP due to the financial asset of RBSE.

 

 

 

 

 

Income Tax (IR) and Social Contribution on Net Income (CCSL) - R$ Thousand

2Q17

2Q16

Variation (%)

Analysis

Current IR and CSLL

139

-44

415.9

The variation was mainly due to: (i) taxable income in the 1Q17 was inferior to the one calculated in the 1Q16, due to decrease of the financial revenue.

Deferred IR and CSLL

-

-

0

Not applicable

Tax incentives

-

-

0

Not applicable

 

 

 

 

 

 

24

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex II - 2Q17

Financial Information of the Subsidiaries

Eletroacre

        
         

Result Analysis

         

The Company had in 2Q17 a result 29.7% lower than the one recorded in the 2Q16, going from a loss of R$ 59.2 million in 2Q16 to a loss of R$ 76.8 million in 2Q17, mainly due to the reasons described below.

         

Operating Revenue

         

The Net Operating Revenue had an increase of 3.8% in 2Q17, compared to the 2Q16, going from R$ 133.6 million in 2Q16 to R$ 138.7 million in 2Q17. The variations of each income account are detailed below:

         

Gross Revenue - R$ Thousand

2Q17

2Q16

Variation (%)

Analysis

Distribution

 

 

 

 

Supply

145,105

137,878

5.2

The variation was mainly due to: (i) Average tariff readjustment of 8.37% effective as of Dec / 16.

Short Term Market

42,162

0

100.0

The variation was mainly due to: (i) rerating in 2017, when this revenue was first recognized, it was previously accounted for as recovery of expenses with electrical power.

Construction Revenue

10,835

18,807

-42.4

No effect in the result, due to equivalent expense, however, the variation was mainly due to: (i) Reduction of investments made by the company, (ii) inflows of funds from the PLPT that are classified as special obligations, which further reduces the company's remunerated investment.

CVA Revenue

2,675

19,421

-86.2

The variation was mainly due to: (i) Reduction as a result of the amortization of CVA approved over the previous period at 2.8 million per month.

Other Operating Revenues

3,300

6,011

-45.1

The variation was mainly due to: (i) Decrease in VNR revenue, due to the reduction in the IPCA since this revenue is the multiplication of the BRR update by this index.

Deductions to the Operating Revenue

-65,293

-48,446

34.8

The variation was mainly due to: (i) Recognition of the reversal of PIS and COFINS credits in 2Q17, which were being discussed in the Administrative sphere, but with the adhesion to the PRT - Programa de Regularização Tributária (Tax Regularization Program), the administrative process was withdrawn.

ROL

138,784

133,671

3.8

The variation was due to the reasons explained above.

 

 

 

 

 

Operating Costs and Expenses

The operating costs and expenses had an increase of 14.5% in 2Q17 compared to the 2Q16, going from R$ 146 million to R$ 167 million, presenting the variations listed below:

 

 

 

 

 

Personnel, Material, Services and Others (PMSO) - R$ Thousand

2Q17

2Q16

Variation (%)

Analysis

Personnel

-11,984

-10,085

18.8

The variation was mainly due to: (i) salary adjustment according to ACT as of June 2016 at 9.28%, and as of May 2017 at 4.08%; (ii) hiring of new employees according to court order ruling for insourcing of services.

Material

-553

-253

118.6

The variation was mainly due to: (i) Purchase of materials for renovation of the company’s commercial division rooms.

Services

-15,452

-12,402

24.6

The variation was mainly due to: (i) adjustments of contracts, (ii) beginning of the inspection contract of consuming units, which underwent an increase of 15 teams to 50.

Others

-10,201

-26,809

-61.9

The variation was mainly due to: (i) Reduction due to a notice of violation applied by SEFAZ in the previous year, what did not happen in this period.

Donations and contributions

0

0

0

Other operating expenses

-10,201

-26,809

-62

TOTAL PMSO

-38,190

-49,549

-22.9

The variation was due to the reasons explained above.

Operating Costs - R$ Thousand

2Q17

2Q16

Variation (%)

Analysis

Energy Purchased for Resale

-137,961

-52,570

162.4

The variation was mainly due to: (i) change in the energy generation contract into the isolated system. In the 2Q16, the company purchased fuel to produce energy, currently, this is a responsibility of PIE - Independent Energy Producer. As a result, we do not have a cost with fuel purchase, besides, the expenses with energy purchased for resale increased.

Fuel

0

-39,466

304.9

The variation was mainly due to: (i) Change in the power generation contract for the isolated system. In 2Q16, the company bought fuel to produce energy, today it is the responsibility of PIE. As a consequence, we no longer have the cost of buying fuel. The 49.3 million are recoveries of generation expenses of the Sectoral Fund CCC.

(-) Recovery of CCC Expenses

49,320

15,390

Charges for the Use of the Electricity Grid

-1,701

-1,454

17.0

The variation was mainly due to: (i) Increase of charges due to adjustment of Allowed Annual Revenue (RAP) in the order of 16% as of July 2016, thus impacting 2Q17.

Construction Expense

-10,835

-18,807

-42.4

The variation was mainly due to: (i) Reduction of IGPM, since such revenue results from the updating of BRR by said index, amounting to the same of construction revenue.

Depreciation and Amortization

-5,750

-4,347

32.3

The variation was mainly due to: (i) Increase of fixed assets in service, as a result of the company’s effort to optimize the volume of unitizations.

Operating Provisions - R$ Thousand

2Q17

2Q16

Variation (%)

Analysis

 

-21,556

5,216

-513.3

The variation was mainly due to: (i) booking if provision connected to the reversal of credits for loss of power in the generation process in the isolated system amounting to 138 million.

         

Financial Result - R$ Thousand

2Q17

2Q16

Variation (%)

Analysis

Financial Investments Incomes

522

233

124.0

The variation was mainly due to: (i) financial availability for investment in a better company’s cash generation.

Debt Charges

-4,327

-12,932

-66.5

The variation was mainly due to: (i) Suspension of the enforceability of contracts celebrated with Eletrobras by Ordinary Appeal - RO up to 12/31/2017

Interest paid in arrears for energy sold

3,270

7,451

-56.1

The variation was mainly due to: (i) decrease of the IPCA incident used over receivables delayed

Net Monetary Correction

-6,886

-39,153

-82.4

The variation was mainly due to: (i) decrease of the IPCA incident used over receivables rights

Asset Update/CVA Regulatory Liability

0

0

0.0

Not applicable

Other Revenue/Financial Expenses

-75,436

-2,957

2451.1

The variation was mainly due to: (i) Registration of financial charges of the infraction notices process applied by SEFAZ/AC of credit reversal referring to the loss of energy in the process of generation in the isolated system in the amount of R$ 76 million.

 

25

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex II - 2Q17

Financial Information of the Subsidiaries

AMAZONAS D

        
         

Result Analysis

         

The Company had in 2Q17 a result 87% higher than the one recorded in 2Q16, going from a loss of R$ 487 million in 2Q16 to a loss of R$ 61 million in 2Q17, mainly due to the reasons described below.

         

Operating Revenue

         

The Net Operating Revenue had na increase of 1% in 2Q17, compared to the 2Q16, going from R$ 748 million in 2Q16 to R$ 759 million in 1Q17. The variations of each income account are detailed below:

         

Gross Revenue - R$ Thousand

2Q17

2Q16

Variation (%)

Analysis

Generation

 

 

 

 

Supply

0

0

0.0

Not applicable

Short Term Market (CCEE)

0

0

0.0

Not applicable

Construction Revenue

0

4,304

0.0

Not applicable

Distribution

 

 

 

 

Supply

690,760

760,744

-9.2

The variation was mainly due to: (i) migration of consumers to the free contracting environment (ACL). In 2Q16, the company started to serve its first free/special consumers, migrating to the free contracting environment (ACL). Such migration had a negative impact on the supply.

Short Term Market (CCEE)

171,539

131,640

100.0

The variation was mainly due to: (i) Growth of power settled in MCP - Short Term Market, due to the migration of consumers to ACL, on account of this, the power contracted to serve such consumers started being settled within MCP.

Construction Revenue

49,993

62,858

-20.5

No effect on the result, given that the revenue is fully settled by Construction Costs, at the same amount, and corresponds to the Company’s investment over the period with concession assets

CVA Revenue

30,184

-41,989

171.9

The variation was mainly due to: (i) amortization of regulatory asset approved at 2Q16.

Other Operating Revenues

7,796

90,632

-91.4

The variation was mainly due to: (i) recording in 2016 of CDE - EQUILIBRIO DA REDUCAO DE TARIFAS (balance of tariff reduction), which refers to the registration of amounts receivable in order to ensure the economic and financial balance due to the reduction of the tariffs of the distribution concessionaires, in accordance with ANEEL Resolution No. 1,980, of 27 Of October 2015.

Deductions to the Operating Revenue

-191,125

-283,421

-32.6

The variation was mainly due to: (i) decrease of the supply revenue, reflecting the decrease of the PIS, COFINS, and ICMS tax base.

ROL

759,147

724,768

4.7

The variation was due to the reasons explained above.

         

Operating Costs and Expenses

The operating costs and expenses had an increase of 27.5% in 2Q17 compared to the 2Q16, going from R$ 943 million to R$ 683 million, presenting the variations listed below:

         

Personnel, Material, Services and Others (PMSO) - R$ Thousand

2Q17

2Q16

Variation (%)

Analysis

Personnel

-92,444

-92,361

0.1

There was no relevant variation among periods, showing reduction of costs that compensated the adjustment effects around 9% of the Collective Bargaining Agreement (2016-2017) occurred on the 2Q16 due to labor agreement approved by teh court held after the ordinary base of the ACT and 4% of the adjustment of 2017-2018 from May 2017.

Material

-7,830

-6,964

12.4

The variation was mainly due to: (i) an impact of the reversal of PIS/COFINS credits as a result of the commercial losses that happened only after January 2017.

Services

-60,377

-59,964

0.7

There was no relevant variation from one period to the other

Others

-57,227

-57,512

-0.5

The variation was mainly due to: (i) as of the publication of Order no. 1583/15 dated May 18, 2015, monthly reimbursements of CCC started undergoing a cutting factor of regulatory losses. The index of 2Q17 was higher than that of 2Q16.

Donations and contributions

0

0

0

Other operating expenses

-57,227

-57,512

0

TOTAL PMSO

-217,878

-216,801

0.5

 

         

Operating Costs - R$ Thousand

2Q17

2Q16

Variation (%)

Analysis

Energy Purchased for Resale

-431,553

-467,726

-7.7

The variation was mainly due to: recording of 214.700 thousand out of the overcontracting of energy. The distributors connected to SIN will not be subject to the limits of subcontracting over the 3 years following to the interconnection (Decree no. 7246/2010), which is the case of AmD. ANEEL has already recognized, over the period from May 2015 to August 2016, the amount of R$ 215 million to be considered over IRT 2017.

Fuel

-892,223

-837,453

-26.4

The variation was mainly due to: (i) decrease of the average ACR, going from R$ 295.10 in 2016 to R$ 204.84 in 2017, affecting the recovery of CCC Expenses.

(-) Recovery of CCC Expenses

1,008,016

994,851

Charges for the Use of the Electricity Grid

-16,629

-19,636

-15.3

The variation was mainly due to: (i) growth of power settled in MCP (Short therm market) due to the migration of consumers to ACL, also reducing the charges of the use of grid.

Construction Expense

-49,993

-67,162

-25.6

No effect on the result, given that the expense is fully settled by Construction Revenue, at the same amount, and corresponds to the Company’s investment over the period with concession assets

Depreciation and Amortization

-36,008

-25,901

39.0

The variation was mainly due to: (i) increase of the Amortization of the Distribution Intangible Asset, pursuant to ICPC-01, resulting from the reduction of the concession term.

 

 

 

 

 

Operating Provisions - R$ Thousand

2Q17

2Q16

Variation (%)

Analysis

 

338,766

-272,620

-224.3

The variation was mainly due to: (i) Contingencies: Reversal mainly arising out of the reduction of the amounts under litigation of 2 legal proceedings filed by Genrent (lessor of the Generating Unit) of R$ 64 million, (ii) Reversal of onerous contracts amounting to R$ 434 million: HPP Aparecida as a result of the resumption of gas, amounting to R$ 54 million; Surplus of Impairment amounting to R$ 380 million; (iii) Reversal of Impairment as of result of the Intangible asset amounting to R$ 32 million, and; (iv) Reversal of Allowance for Tax Liability, amounting to R$ 59 million;

       

 

Financial Result - R$ Thousand

2Q17

2Q16

Variation (%)

Analysis

Financial Investments Incomes

3,466

1,550

123.6

The variation was mainly due to: (i) increase of funds available for investment.

Leasing Charges

-80,320

-85,654

-6.2

The variation was mainly due to: (i) variation of IGPM index for updating of contracts.

Debt Charges

-497,555

-53,842

824.1

The variation was mainly due to: (i) charges arising from new loans. From July 2016 to June 2017, the amount of R$ 933 million of RGR was raised; Ii) adjustment of current debt with Petrobras / Cigás and BR Distribuidora.

Interest paid in arrears for energy sold

17,511

30,938

-43.4

The variation was mainly due to: (i) reduction of invoiced energy

Net Exchange Variations

-78

-1,397

-94.4

The variation was mainly due to: (i) In 2Q16 there was a record of exchange variation resulting from the exchange difference between the date of acquisition and the effective entry of imported generating groups in the amount of R$ 4.6 million, which did not occur in 2Q17.

Net Monetary Correction

107,261

5,272

1934.5

The variation was mainly due to: (i) the atypical effect resulting from the reclassification of interest on the receivables from contracts repactado by the CDE-CCC Fund in 2Q17 for active monetary restatement, while in 2Q16 they were classified in the interest and fines group (Other revenues).

Asset Update/CVA Regulatory Liability

-5,333

-5,665

-5.9

The variation was mainly due to: (i) amortization of regulatory assets and liabilities approved in IRT of 2016.

Other Revenue/Financial Expenses

-67,582

-132,636

-49.0

The variation was mainly due to: (i) proceeding monetary correction of 14 proceedings filed by the Independent Energy Producers (PIE) against the Company, such proceedings were recorded under accounting records in December 2016.

 

26

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex II - 2Q17

Financial Information of the Subsidiaries

BOA VISTA ENERGIA

        
         

Result Analysis

         

The Company had in 2Q17 a result 47% higher than the one recorded in 2Q16, going from a loss of R$ 83 million in 2Q16 to a loss of R$ 51 million in 2Q17, mainly due to the reasons described below.

         

Operating Revenue

         

The Net Operating Revenue had an increase of 38% in 2Q17, compared to the 2Q16, going from R$ 66 million in 2Q16 to R$ 98 million in 2Q17. The variations of each income account are detailed below:

         

Gross Revenue - R$ Thousand

2Q17

2Q16

Variation (%)

Analysis

Generation

 

 

 

 

Supply

0

8,327

-100.0

The variation was mainly due to: (i) as of January 2017, owing to the fact that the company stopped performing the supply operation of energy for CERR - Company of the State of Roraima, owing to the fact that its area until then supplied by CERR started being temporarily served by Boa Vista Energia, in accordance with MME Ordinance 920/2015.

Distribution

 

 

 

 

Supply

104,085

67,320

54.6

The variation was mainly due to: (i) application of the average rate adjustment of 42% approved in November 2015, which was suspended by legal action, but started being effective as of mid-August 2016, when the injunction that prevented the adjustment was suspended; and (ii) the expansion of the energy supply service to the State's countryside, adding 43 thousand consumers, due to the service coverage to the CERR area.

Short Term Market

0

0

0.0

Not applicable

Construction Revenue

7,965

6,988

14.0

No effect on the result, due to equivalent construction expense, however, the variation was mainly due to: (i) increase in the performance of works.

CVA Revenue

6,037

-18

33,638.9

The variation was mainly due to: (i) average ACR for the 2017 period was lower compared to 2016. In addition, Aneel's readjustment in November 2016 was negative in November of about 21%.

Other Operating Revenues

11,317

2,096

439.9

The variation was mainly due to: (i) increase of tax subsidies connected to the tax mode; and (ii) revenue from the use of poles.

Deductions to the Operating Revenue

-31,827

-18,316

73.8

The variation was mainly due to: (i) In 2016 the PIS and COFINS credits (used for compensation) on purchased/generated energy were higher compared to the energy invoiced in the period due to the 42.5% readjustment that the application by default was suspended and that it was applied In August 2016 without being retroactive; (Ii) change in the methodology for calculating pees and cofins from January 2017.

ROL

97,577

66,397

47.0

The variation was mainly due to the facts explained above.

 

 

 

 

 

Operating Costs and Expenses

The operating costs and expenses had an increase of 4.8% in 2Q17 compared to the 2Q16, going from R$ 111 million to R$ 117 million, presenting the variations listed below:

         

Personnel, Material, Services and Others (PMSO) - R$ Thousand

2Q17

2Q16

Variation (%)

Analysis

Personnel

-22,388

-18,639

20.1

The variation was mainly due to: (i) average wage adjustment of 9% of ACT 2016/2017 which took place only in July 2016 owing to the fact that the collective bargaining agreement happened after the base date of May 2016; (ii) adjustment of 4% of ACT 2017/2018 happened in May 2017; (ii) Hiring of 67 new employees happened as of May 2016, owing to the court order for insourcing of services; (iii) effects of the adjustments of ACT for 51 employees which were assigned by CERR to continue with the services within the State’s countryside.

Material

-710

57

-1,345.6

The variation was mainly due to: (i) supply, as of 2017, to the State’s countryside , which was previously served by CERR in 2016, which was offset by the reclassification of the balance of material that were for investment in 2016, which is why the account was reversed.

Services

-8,896

-3,878

129.4

The variation was mainly due to: (i) supply, as of 2017, to the State’s countryside , which was previously served by CERR in 2016, total of 14 cities.

Others

-2,226

-1,068

108.4

The variation was mainly due to: (i) Reclassification of some accounts givenchanges in the system to fit the Plan of Accounts of Aneel

Donations and contributions

0

0

0.0

Other operating expenses

-2,226

-1,068

108.4

TOTAL PMSO

-34,220

-23,528

45.4

The variation was mainly due to the facts explained above.

         

Operating Costs - R$ Thousand

2Q17

2Q16

Variation (%)

Analysis

Energy Purchased for Resale

-67,767

-44,983

50.7

The variation was mainly due to: (i) increase of the number of consumers in the capital (3,614 new units) and in the countryside (about 43 thousand new consumers), including the area previously served by CERR.

Fuel

11,940

-75,686

-66.7

The variation was mainly due to: (i) in 2017 the usage of the oil was lower compared to 2016 and also the cost was lower given the variation in the ACR that went from R$ 295 MW/h to R$ 204 MW/h .

(-) Recovery of CCC Expenses

-27,528

28,940

Charges for the Use of the Electricity Grid

0

0

0.0

Not applicable

Construction Expense

-7,965

-6,988

14.0

No effect on the result, due to equivalent revenue entry, however, the variation was mainly due to: (i) increase in the performance of works.

Depreciation and Amortization

-2,579

-2,718

-5.1

The variation was mainly due to: (i) The addition of assets was smaller than in the period, due to lowr unitization.

 

 

 

 

 

Operating Provisions - R$ Thousand

2Q17

2Q16

Variation (%)

Analysis

 

-6,854

-16,297

-57.9

The variation was mainly due to: (i) the fact there is no more supply of energy to CERR in 2017, and, as a result, there is no provision for PCLDs - Allowance for Doubtful Accounts on the energy supplied and not paid. In 2016, the allowance of supply to CERR was R$ 26.7 million and corresponded to 86% of the amount under allowance.

         

Financial Result - R$ Thousand

2Q17

2Q16

Variation (%)

Analysis

Financial Investments Incomes

282

643

-56.1

The variation was mainly due to: (i) greater availability of funds in account, for investment.

Debt Charges

-534

-3,056

-82.5

The variation was mainly due to: (i) renegotiation of loan and financing contracts with Eletrobras holding.

Interest paid in arrears for energy

-16,326

-5,160

216.4

The variation was mainly due to: (i) monetary correction of debt with Petrobras and (ii) updatings, interests and fines of energy purchased for resale with Eletronorte and not paid

Net Monetary Correction

3,431

-3,619

-194.8

The variation was mainly due to: (i) decrease of the adjustment of provisions for PCLDs - Allowance for Doubtful Accounts, particularly for CERR, due to the reduction of PCLDs.

Asset Update/CVA Regulatory Liability

247

50

394.0

The variation was mainly due to: (i) Recognition of the CVA for 2016 that should have been applied since November 2015, but there was a preliminary injunction that prevented the readjustment of the sale rate. As of October 2016, the adjustment was allowed.

Other Revenue/Financial Expenses

-720

3,125

-123.0

The variation was mainly due to: (i) Reclassification of accounts to comply with Plan of Accounts of Aneel

 

27

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex II - 2Q17

Financial Information of the Subsidiaries

CEAL

        
         

Result Analysis

         

The Company had in 2Q17 a result 2,8% lower than the one recorded in 2Q16, going from a loss of R$ 52 million in 2Q16 to a loss of R$ 53 million in 2Q17, mainly due to the reasons described below.

         

Operating Revenue

         

The Net Operating Revenue had an increase of 33.3% in 2Q17, compared to the 2Q16, going from R$ 300 million in 2Q16 to R$ 400 million in 2Q17. The variations of each income account are detailed below:

         

Gross Revenue - R$ Thousand

2Q17

2Q16

Variation (%)

Analysis

Distribution

 

 

 

 

Supply

441,971

419,090

5.5

The variation was mainly due to: (i) increase of consumption in the rural class; and (ii) program for combat against loss.

Short Term Market

0

0

0.0

 

Construction Revenue

32,511

32,079

1.3

No effect on the result, due to equivalent construction expenses

CVA Revenue

106,431

-10,725

1,092.4

The variation was mainly due to: (i) the amortization in 2017 is positively impacting on the result, as it was negatively recorded in 2016; and (ii) recording of CVA and Financial Items and subcontracting as a positive entry.

Other Operating Revenues

22,386

23,789

-5.9

The variation was mainly due to: (i)Reduction in rental revenues due to the termination of the infrastructure sharing agreement.

Deductions to the Operating Revenue

-203,208

-164,170

23.8

The variation was mainly due to: (i) Reduction of the CDE contribution and ACR loan, according to ANEEL resolution; (Ii) increase in PIS / COFINS due to terminations of the Federal Revenue, associated with Non-Technical Losses

ROL

400,091

300,063

33.3

The variation was due to the reasons explained above.

         

Operating Costs and Expenses

The operating costs and expenses had an increase of 17.5% in 2Q17 compared to the 2Q16, going from R$ 424 million to R$ 350 million, presenting the variations listed below:

         

Personnel, Material, Services and Others (PMSO) - R$ Thousand

2Q17

2Q16

Variation (%)

Analysis

Personnel

-48,143

-35,118

37.1

The variation was mainly due to: (i) Readjustment resulting from ACT 2016-2018 (effect of 9% of the 2016-2017 adjustment occurred after 2Q16 due to the filing of collective dissident after the ordinary base date of the ACT and 4% of the 2017-2018 readjustment as of May 2017; (Ii) payment of overtime and retroactive harm to 2012 as per judicial order, (iii) admission of 95 employees to comply with the TAC, in substitution of outsourced employees, and (iv) adjustment of the health plan by 15.09%

Material

-369

-487

-24.2

The variation was mainly due to: (i) Increase with maintenance in distribution network; (Ii) registration re-registration of the consumer; and (iii) small emergency reforms

Services

-31,112

-22,344

39.2

The variation was mainly due to: (i) Anti-loss itemization to meet the PPTS; (ii) reclassification of expenses recorded as an investment in 2016; (iii) a 45% increase in commercial technical services due to atypical climatic conditions in the months of April to June; (iv) increase in surveillance, Consumer Telecommunication and collection agent resulting from contractual corrections; And (iv) vegetative growth of the market

Others

-4,305

-5,734

-24.9

The variation was mainly due to: (i) in 2017, there was increase in the return to the consumer owing to surpassing DIC/FIC.

Donations and contributions

-60

-27

122.2

Other operating expenses

-4,245

-5,707

-25.6

TOTAL PMSO

-83,929

-63,683

31.8

The variation was due to the reasons explained above.

         

Operating Costs - R$ Thousand

2Q17

2Q16

Variation (%)

Analysis

Energy Purchased for Resale

-303,838

-163,237

86.1

The variation was mainly due to: (i) Increase in contracts for availability resulting from tariff readjustments and increase of the variable portion referring to the thermal dispatch; (ii) increased MCP accounting due to involuntary exposure to the PLD increased by the compulsory assignment of MCSD Energia Nova contracts; And (iii) the increase in hydrological risk.

Fuel

0

0

0.0

Not applicable

(-) Recovery of CCC Expenses

0

0

Charges for the Use of the Electricity Grid

-11,181

-21,619

-48.3

The variation was mainly due to: (i) decrease of Charges of service of System - ESS.

Construction Expense

-32,511

-32,079

1.3

No effect on the result, due to equivalent construction expense, however, the variation was mainly due to the Reduction of new fixed assets.

Depreciation and Amortization

-9,417

-8,263

14.0

The variation was mainly due to: (i) task force that increased the number of unitizations over the period.

 

 

 

 

Operating Provisions - R$ Thousand

2Q17

2Q16

Variation (%)

Analysis

 

-13,751

-23,498

-41.5

The variation was mainly due to: (i) Reduction of receivable losses with uncollectible consumers, of the public service class whose amount was paid in November 2016 in 240 installments of approximately R$ 1,044 million per month.

 

 

 

 

 

Financial Result - R$ Thousand

2Q17

2Q16

Variation (%)

Analysis

Financial Investments Incomes

1,612

1,040

55.0

The variation was mainly due to: (i) higher availability for investment.

Debt Charges

-67,758

-50,224

34.9

The variation was mainly due to: (i) renegotiation of the debt service with Eletrobras; and (ii) charges for ordinary installments - Tax Recovery Program - PRT.

Interest paid in arrears for energy sold

12,214

5,403

126.1

The variation was mainly due to: (i) interests levied upon the receipt of default of customers and new installments.

Net Exchange Variations

-57

166

-134.3

The variation was mainly due to: (i) variation of the dollar in the period.

Net Monetary Correction

-1,400

3,532

-139.6

The variation was mainly due to: (i) Decrease for the correction of invoices paid in arrears owing to the decrease of default; (ii) Monetary correction of debt with suppliers - The company is non-breaching.

Asset Update/CVA Regulatory Liability

-269

3,841

-107.0

The variation was mainly due to: (i) amortization of CVA and financial items approved in 2016; and (ii) constitution of new 2016-2017 cycle.

Other Revenue/Financial Expenses

-25,634

-2,945

770.4

The variation was mainly due to: (i) Updating of escrow deposits; (ii) Interests on PIS/COFINS and CSLL arising from the reversal of credits with non-technical losses in the assessment of the period from May 2012 to April 2017.

 

28

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex II - 2Q17

Financial Information of the Subsidiaries

CERON

 

 

 

 

 

 

 

 

 

Result Analysis

 

 

 

 

 

The Company had in 2Q17 a result 84% higher than the one recorded in 2Q16, going from a loss of R$ 105 million in 2Q16 to a loss of R$ 193 million in 2Q17, mainly due to the reasons described below.

 

 

 

 

 

Operating Revenue

 

 

 

 

 

The Net Operating Revenue had a decrease of 36% in 2Q17, compared to the 2Q16, going from R$ 449 million in 2Q16 to R$ 289 million in 2Q17. The variations of each income account are detailed below:

 

 

 

 

 

Gross Revenue - R$ Thousand

2Q17

2Q16

Variation (%)

Analysis

Generation

 

 

 

 

Supply

0

0

0.0

Not applicable

Distribution

 

 

 

 

Supply

365,158

404,975

-9.8

The variation was mainly due to: (i) the reduction posted happened as a result of the adjustment of the average of -6%, resulting from the total reduction of market of 3%, given that, in the captive industrial class, there was reduction of 21.0%, and the return of the Backup Energy Charge of Angra III, carried out in April 2017 with average reduction of rate of 4.7%, the amount of which, in April, was R$ 15.305 thousand, and for the subsequent months for Group A = Average Reduction of 1.45%, for Group B = Average Reduction of 1.17%, effects compared to the Tax Adjustments of 2016.

Short Term Market

43,066

20,596

109.1

The variation was mainly due to: (i) the energy settled in the short term market is impacted by the increase of PLD, taking into account the fact that, in 2016, the average amount was R$ 43.55 and, in 2017, is at R$ 172.33; (ii) overcontracting in 2016 over the period compared was, on average, 11.2% and, in 2017, is 23.3% on average.

Construction Revenue

47,965

70,324

-31.8

The variation was mainly due to: (i) reduction of additions to current fixed assets of the distribution system.

CVA Revenue

-2,862

113,652

-102.5

The variation was mainly due to: (i) R$ 62,987 of CVA, a constitution smaller than that in the previous year, and R$ 23.997 had an amortization of CVA connected to the 2016/2017 cycle; (ii) over the period of 2017, there was no record of CVA tax flag owing to the fact that the collection was suspended by injunction, whereas 2016 had an amount of R$ 19,992.

Other Operating Revenues

-1,353

22,005

-106.1

The variation was mainly due to: (i) Reduction of transfer of Low Income and Tariff Discount, whose amounts are homologated by ANEEL.

Deductions to the Operating Revenue

-163,033

-182,680

-10.8

The variation was mainly due to: (i) reduction of ICMS as a result of the negative tax adjustment and reduction of captive market, taking into account the migration of industrial and commercial clients to free consumers; (ii) PIS/PASEP and COFINS, reduction owing to the impacts already mentioned on ICMS plus the decrease of credits on the purchase of energy, taking into consideration the disregard of credits corresponding to commercial energy loss; (iii) reduction of CDE Use and CDE ACR Quotas, upon ruling by ANEEL.

ROL

288,941

448,872

-35.6

The variation was due to the reasons explained above.

 

 

 

 

 

Operating Costs and Expenses

The operating costs and expenses had an increase of 9.6% in 2Q17 compared to the 2Q16, going from R$ 365 million to R$ 330 million, presenting the variations listed below:

 

 

 

 

 

Personnel, Material, Services and Others (PMSO) - R$ Thousand

2Q17

2Q16

Variation (%)

Analysis

Personnel

-35,704

-29,784

19.9

The variation was mainly due to: (i) Readjustment resulting from ACT 2016-2018 (effect of 9% of the 2016-2017 adjustment occurred after 2Q16 due to the filing of collective dissident after the ordinary base date of the ACT and 4% of the 2017-2018 readjustment as of May 2017.

Material

-1,556

-1,363

14.2

The variation was mainly due to: (i) Increase in the consumption of fleets as a result of the intensification of cut and reconnection and other operating services, (ii) Purchase of seals for the commercial area; and (iii) Increase in the materials for building renovations in Service Offices, Substations and Warehouses.

Services

-33,392

-28,992

15.2

The variation was mainly due to: (i) increase mainly in the expenses with the Maintenance of Grids and Substations as a result of the addition of the service of Mowing and Rights of Way, which, in 2016, were not established over the compared period.

Others

7,376

-19

-38,921.1

The variation was mainly due to: (i) Costs of Legal Rates – R$ 1.4 million in 2016 to R$ 3.6 million as a result of the amount of indemnities paid in 2017; (ii) DIC/FIC/DMIC - R$ 12.8 million in 2016 to R$ 10.2 million – reduction as a result of the improvement of services to consumers; (iii) Recovery of Expenses - R$ - 6.5 million to R$ - 2.0 million - The reduction of the recovery of expenses under the account was due to PIS/PASEP and COFINS, which were recovered out of time in connection with the rectifications of SPEDs. In turn, in 2017, expenses are already being recorded net of taxes; (iv) Others – The variation of others was mainly due to the reratings below:
Labor Indemnities (2,918) for provision for contingencies in 2017
Indemnities of legal petitions (18,009) for provision for contingencies in 2017
Loss in the receipt of credits (21,893) for PCLD provision in 2017
VNR 34,212 for ROB in 2017

Donations and contributions

-73

-54

35.2

Other operating expenses

7,449

35

21,182.9

TOTAL PMSO

-63,276

-60,158

5.2

The variation was due to the reasons explained above.

         

Operating Costs - R$ Thousand

2Q17

2Q16

Variation (%)

Analysis

Energy Purchased for Resale

-548,873

-321,568

70.7

The variation was mainly due to: (i) the increase posted has as main reasons: a) Increase of the Cutting Factor to 11.6%, resulting in the increase of the Disregard in the reimbursement of credits with CCC; (ii) ascertainment of the reversal of credits of PIS/COFINS over the last 5 years, in keeping with the option into the Tax Regularity Program - PRT/2017 amounting to R$ 28.7 million, the amount of which was not used and returned to the original cost account (energy purchased for resale); (iii) increase of average PLD of R$ 43.55 in 2016 to R$ 172.33 in 2017. Such increase directly impacts the costs of Short Term settlement in the operation of the Contract with Termonorte; and (iv) partial recognition of CNH Contract.

Fuel

0

0

100

The variation was mainly due to: (i) in 2Q16, there was no investigation of CCC rights for Termonorte Contract, owing to the fact that the amount of ACR was R$/MWh 295.10, with a very low PLD in 2Q16, in turn, in 2T17, ACRmed reached R$/MWh 204.84, with a higher PLD, which led to amounts reimbursable to CCC Fund.

(-) Recovery of CCC Expenses

191,858

0

Charges for the Use of the Electricity Grid

-4,910

-4,983

-1.5

The variation was mainly due to: (i) increase owing to adjustment of rates for collection of said charges.

Construction Expense

-47,965

-70,324

-31.8

No effect on the result, due to equivalent construction revenue, however, the variation was mainly due to the reduction of new works.

Depreciation and Amortization

-10,366

-8,623

20.2

The variation was mainly due to: (i) Increase as a result of the unitizations that were performed from November 2016 to January 2017.

         

Operating Provisions - R$ Thousand

2Q17

2Q16

Variation (%)

Analysis

 

-436

-9,588

-95.5

The variation was mainly due to: (i) increase as a result of the rerating of loss with credits from clients under PCLD and the rerating of loss of legal proceedings under provision for contingencies. They were rated under other operating expenses.

Financial Result - R$ Thousand

2Q17

2Q16

Variation (%)

Analysis

Financial Investments Incomes

770

2,197

-65.0

The variation was mainly due to: (i) revenue from financial investments - reduction as a result of the decrease of financial investments of CCC funds for paying expenses with standalone System

Debt Charges

-33,980

-28,278

20.2

The variation was mainly due to: (i) increase as a result of RO debts which incorporated the financial charges of principal.

Interest paid in arrears for energy sold

9,641

10,609

-9.1

The variation was mainly due to: (i) late payment addition w/o sold/purchased energy – reduction as a result of improvement of TAF.

Net Monetary Correction

-26,250

-23,331

12.5

The variation was mainly due to: (i) reduction as a result of rates invested on CCC receivables that, in 2016, were higher than that in 2017; (ii) rerating of other financial expenses of adjustments of debt with power suppliers and CCDs, as a result of the recognition of adjustments and interests on the addition of PRT in May 2017.

Asset Update/CVA Regulatory Liability

-128

-393

-67.4

The variation was mainly due to: (i) updating of regulatory asset (installment "a" - CVA) - reduction owing to the amount set apart as provision as regulatory asset for the 2017/2018 cycle being smaller than the amount of 2016/2017

Other Revenue/Financial Expenses

-35,837

-39,301

-8.8

The variation was mainly due to: (i) increase connected to the fact that, in 2016, PIS/PASEP and COFINS were recognized under the financial revenues on the amount of Contract with Termonorte and, over this year, the charges are being levied on the variation for the period; (ii) rerating for passive monetary variations for adjustments of CCDs and Eletronorte Contract.

 

29

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex II - 2Q17

Financial Information of the Subsidiaries

 

CEPISA

        
         

Result Analysis

         

The Company had in 2Q17 a result 147% higher than the one recorded in 2Q16, going from a loss of R$ 93 million in 2Q16 to an increase of R$ 43 million in 2Q17, mainly due to the reasons described below.

         

Operating Revenue

         

The Net Operating Revenue had an increase of 22% in 2Q17, compared to the 2Q16, going from R$ 307 million in 2Q16 to R$ 374 million in 2Q17. The variations of each income account are detailed below:

         

Gross Revenue - R$ Thousand

2Q17

2Q16

Variation (%)

Analysis

Distribution

 

 

 

 

Supply

259,702

411,060

-36.8

The variation was mainly due to: (i) rerating of the revenue of distribution to other revenues and exceeding revenue and reactive surpluses for special obligations in compliance with the MCSE. By analyzing Supply and Other Operating Revenues as a whole, to disregard the effect on the rerating between accounts, one may see that there was an increase of invoicing over the quarter.

Construction Revenue

 

 

 

 

Short Term Market

13,467

0

100.0

The variation was mainly due to: (i) overcontracting recorded in March/2017, with impact on April 2017, whereas, in the same period of 2016, CEPISA was subcontracted.

Construction Revenue

35,205

24,096

46.1

No effect on the result, due to equivalent construction expense, however, the variation was mainly due to the reduction of works.

CVA Revenue

56,649

10,943

417.7

The variation was mainly due to: (i) amounts of CVA with effects resulting from the positive constitution and amortization in 2017 (active CVA), whereas, in 2016, result was negative (passive CVA).

Other Operating Revenues

204,757

40,717

402.9

The variation was mainly due to: (i) rerating of the revenue of distribution to other operating revenues.

Deductions to the Operating Revenue

-195,389

-179,405

8.9

The variation was mainly due to: (i) increase in revenue.

ROL

374,391

307,411

21.8

The variation was due to the reasons explained above.

         

Operating Costs and Expenses

The operating costs and expenses had an increase of 16.6% in 2Q17 compared to the 2Q16, going from R$ 389 million to R$ 324 million, presenting the variations listed below:

         

Personnel, Material, Services and Others (PMSO) - R$ Thousand

2Q17

2Q16

Variation (%)

Analysis

Personnel

-68,944

-47,122

46.3

The variation was mainly due to: (i) Readjustment resulting from ACT 2016-2018 (effect of 9% of the 2016-2017 adjustment occurred after 2Q16 due to the filing of collective dissident after the ordinary base date of the ACT and 4% of the 2017-2018 readjustment as of May 2017) ; (Ii) increase in the hiring of new employees as of the second half of 2016 due to prioritization by judicial determination.

Material

-3,045

-1,318

131.0

The variation was mainly due to: (i) Increase of expenses with expedient material and support, safety, hygiene and occupational medicine due to the increase of employees due to primary; (Ii) increase of maintenance material, vehicle and fuel repair due to the increase of the fleet, resulting from the primary.

Services

-27,621

-27,130

1.8

The variation was mainly due to: (i) increase of expenses with the collection rate and that of opening and preservation of roads and deforestation.

Others

-17,364

-117,161

-85.2

The variation was mainly due to: (i) reduction of commercial losses.

Donations and contributions

0

0

0

Other operating expenses

-17,364

-117,161

-85

TOTAL PMSO

-116,974

-192,731

-39.3

The variation was due to the reasons explained above.

         

Operating Costs - R$ Thousand

2Q17

2Q16

Variation (%)

Analysis

Energy Purchased for Resale

-292,827

-217,458

34.7

The variation was mainly due to: (i) increase resulting from the reversal of PIS/COFINS Credit on the non-technical losses, as well as a result of the increase of the amounts ascertained under the Surplus and Deficit Compensation Mechanism.

Fuel

0

0

-

Not applicable

(-) Recovery of CCC Expenses

0

0

Charges for the Use of the Electricity Grid

-14,458

-21,966

-34

The variation was mainly due to: (i) there being no need for Backup Power Charge in 2017 and there was a significant reduction of the System Service Charge in 2017, due to greater energy security in the sector. This charge is collected to subsidize the maintenance of reliability and stability of the National Interconnected System.

Construction Expense

-35,205

-24,096

46

No effect for the result, due to consideration of the construction expense, in equal value, although variation results from the net additions over the period.

Depreciation and Amortization

-12,720

-9,562

33

The variation was mainly due to: (i) increase of unitizations.

 

 

 

 

Operating Provisions - R$ Thousand

2Q17

2Q16

Variation (%)

Analysis

 

8,143

112,803

-92.8

The variation was mainly due to: (i) Increase in provisions for litigation of labor and civil claims of R$ 37.5 million; Offset by (ii) reversal of a provision for impairment, impairment of (R$ 59.2 million), as well as reduction of commercial losses in the amount of R$ 106,841. Such amounts of impairment correspond to depreciation and these become more significant due to the proximity of the final base date - December 2017.

       

 

Financial Result - R$ Thousand

2Q17

2Q16

Variation (%)

Analysis

Financial Investments Incomes

16

4

300.0

The variation was mainly due to: (i) increase of temporary investment of funds available in the period.

Debt Charges

-64,498

-42,741

50.9

The variation was mainly due to: (i) increase of refinancings with Eletrobras.

Interest paid in arrears for energy sold

19,783

19,366

2.2

The variation was mainly due to: (i) Updating of overdue credits with consumers (interests and penalties), mainly caused by campaigns for payment in installments.

Net Exchange Variations

0

0

0.0

Not applicable.

Net Monetary Correction

-98,687

-15,331

543.7

The variation was mainly due to: (i) payment in installments of overdue taxes as of April 2016, thus impacting 2Q17.

Asset Update/CVA Regulatory Liability

326

696

-53.2

The variation was mainly due to: (i) Amortization of CVA and financial items approved in 2016; and (ii) constitution of the new cycle.

Other Revenue/Financial Expenses

-6,640

-9,268

-28.4

The variation was mainly due to: (i) Increase of financial discounts; (ii) reduction of default of payments to suppliers.

 

30

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex III - 2Q17

Operating Information of the Subsidiaries

I. Market Data of Eletrobras Companies

         
               

I.1 Installed Capacity – MW

            

Company

Integral Responsability (a)

Integral Responsability under terms of 13,182/15 Law (b)

Integral Responsability under O&M Regime (c)

SPE (d)

SPE under O&M Regime (e)

Physical Aggregation 2017

Total (a+b+c+d+e)

Eletrobras Holding (1)

-

-

-

506

-

92

506

Eletronorte

9,304

-

78

778

-

122

10,160

Chesf

4

1,864

8,399

1,676

-

92

11,942

Furnas

2,130

2,082

4,617

2,591

403

-

11,823

Eletronuclear

1,990

-

-

-

-

-

1,990

Eletrosul

476

-

-

1,593

-

-

2,069

CGTEE

413

-

-

-

-

- 257

413

Itaipu Binacional

7,000

-

-

-

-

-

7,000

Amazonas G&T

695

-

-

-

-

-

695

Distribution Companies

406

-

-

-

-

- 1

406

Total

22,418

3,946

13,094

7,143

403

48

47,004

(1) The Artilleros Wind farm was not considered, because it is an enterprise located abroad.

       
               

I.2 Transmission Lines - Km

 

 

 

 

    

Company

Integral Responsability (a)

Integral Responsability under O&M Regime (b)

SPE (c)

Physical Aggregation 2017

Total (a+b+c)

    

Eletronorte

1,767

10,011

2,072

- 0

13,849

   

Chesf

1,408

18,968

1,653

62

22,029

   

Furnas

1,514

18,608

1,871

- 20

21,993

   

Eletrosul

1,565

9,426

1,092

0

12,083

   

Amazonas G&T

390

-

-

-

390

   

Total

6,643

57,013

6,688

42

70,344

   

 

 

31

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex III - 2Q17

Operating Information of the Subsidiaries

II. Generation Data

                         

II.1 Installed Capacity - MW

                         

II.1.2 Generation Assets and Generated Energy

                         

II.1.2.1 Generation Assets and Generated Energy – Enterprises under Integral Responsability

Eletrobras Companies

Enterprise

Location

Beginning of Operation

End of Operation

Installed Capacity

Energy Assured

Generated Energy (MWh)

RCE

FCE

(State)

(MWh)

(MWh Average)

1Q17

2Q17

MW Médio

Avg Price (R$/MWh)

Contracts and Termination of Contracts in the RCE

MW Average

Eletronorte

Tucuruí Complex

PA

Nov-84

Jul-24

8,535.00

4,140.00

9,414,280

9,065,109

209.07

324.39

PRODUCT AUCTION 2014 - 2019

3,930.93

HPU Samuel

RO

Jul-89

Sep-29

216.75

92.70

189,532

203,229

-

-

-

92.70

HPU Curuá-Una

PA

Apr-77

Jul-28

30.30

24.00

49,951

63,433

-

-

-

24.00

TPU Rio Madeira (1)

RO

Apr-68

Sep-18

119.35

-

-

-

-

-

-

-

TPU Santana (4) (7)

AP

Mar-93

May-19

177.74

22.30

-

-

-

-

-

-

TPU Rio Branco I (2)

AC

Feb-98

Jul-20

18.65

-

-

-

-

-

-

-

TPU Rio Branco II (2)

AC

Apr-81

Jul-20

32.75

-

-

-

-

-

-

-

TPU Rio Acre

AC

Dec-94

Abr/25 

45.49

-

-

-

-

-

-

-

TPU – Santarém (5)

PA

Jun-14

(5)

18.75

-

-

-

-

-

-

-

TPU Senador Arnon Afonso Farias de Mello (3)

 

1st Unit (mach. 2) Dec-90;

 

 

 

 

-

 

 

 

 

RR

2nd Unit (mach.1) Jun-91

Aug-24

85.99

-

-

-

-

-

-

 

3rd Unit (mach.3) Dec-93

 

 

 

 

 

 

 

 

TPU Araguaia (6)

MT

Apr-16

(6)

23.10

-

23,366

25,494

-

-

-

-

Chesf (9)

Curemas

PB

Jun-57

Nov-24

3.52

1.00

3.8

2.93

-

-

-

-

Camaçari (8)

BA

Feb-79

Aug-16

0.00

0.00

-

-

-

-

-

-

Furnas

Mascarenhas de Moraes

MG

Apr-73

Oct-23

476.00

295.00

610,795.94

244,719.26

98

294

13thLEE2014 - Dec/2019 14thLEE2005 - Dec/2017

186.31

Simplício (10)

RJ

Jun-13

Aug-41

305.70

175.40

423,063.93

243,941.52

185

211.59

1stLEN2005 - Dec/2039

2.39

Batalha

MG

May-14

Aug-41

52.50

48.80

23,205.38

24,184.42

47

213.78

1stLEN2005 - Dec/2039

0.35

Serra da Mesa (48,46%) (11)

GO

Apr-98

Nov-39

1,275.00

671.00

565,503.63

578,432.73

221

294.49

13thLEE2014 - Dec/2019 14thLEE2005 - Dec/2017

422.00

Manso (70%) (11)

MT

Oct-00

Feb-35

212.00

92.00

197,229.15

152,786.02

90

194.13

1stLEN2005 - Dec/2037 1stLEN2005 - Dec/2039

(2.08)

Santa Cruz (12)(13)

RJ

Mar-67

Jul-15

500.00

401.20

373,248.76

504,771.67

351

224.09

5thLEN2012 - Dec/2026

7.91

Roberto Silveira (Campos)

RJ

Apr-77

Jul-27

30.00

20.90

0.00

0.00

-

-

-

4.45

Eletronuclear

Angra I

RJ

Jan-85

Dec-24

640.00

509.80

1,391,964

1,148,755

-

-

-

-

Angra II

RJ

Sep-00

Aug-40

1,350.00

1,204.70

2,571,536

2,968,054

-

-

-

-

Eletrosul

HPU Governador Jayme Canet Júnior*

PR

Nov-12

Jul-42

177.94

96.90

294,328

243,432

94.08

205.80

Dec-40

- 0.68

HPU Passo São João

RS

Mar-12

Aug-41

77.00

41.10

117,142

79,491

37.00

210.91

Dec-39

2.85

HPU São Domingos

MS

Jun-13

Dec-37

48.00

36.40

87,441

58,306

36.00

221.41

Dec-41

- 0.32

SHU Barra do Rio Chapéu

SC

Feb-13

May-34

15.15

8.61

17,648

17,168

-

-

NA

8.50

PCH João Borges

SC

Jul-13

Dec-35

19.00

10.14

13,362

13,876

-

-

NA

9.94

WPP Cerro Chato I

RS

Jan-12

Aug-45

30.00

11.33

18,441

24,636

10.71

196.37

Jun-32

0.34

WPP Cerro Chato II

RS

Aug-11

Aug-45

30.00

11.33

18,612

26,120

11.00

207.41

Jun-32

0.05

WPP Cerro Chato III

RS

Jun-11

Aug-45

30.00

11.33

18,533

26,520

10.95

206.81

Jun-32

0.09

WPP Coxilha Seca

RS

Dec-15

May-49

30.00

13.20

22,932

32,329

8.30

161.48

Dec-35

4.57

WPP Capão do Inglês

RS

Dec-15

May-49

10.00

4.50

7,848

11,238

2.80

161.89

Dec-35

1.59

WPP Galpões

RS

Dec-15

May-49

8.00

3.50

6,251

8,706

2.10

163.07

Dec-35

1.31

Megawatt Solar

SC

Sep-14

-

0.93

NA

383

231

-

-

NA

0.01

CGTEE

P. Médici (Candiota) (14)

RS

Jan-74

Jul-15

63.00

49.17

116,296

30,825

-

-

-

 

Candiota III – Fase C

RS

Jan-11

Jul-41

350.00

201.42

238,161

379,666

-

-

35 CCEAR´s - Dec/2023

 

S. Jerônimo (São Jerônimo)

RS

Apr-53

Jul-15

-

-

-

-

-

-

-

 

Nutepa (Porto Alegre)

RS

Feb-68

Jul-15

-

-

-

-

-

-

-

 

Itaipu Binacional

Itaipu Binacional

Brazil (Paraná) and Paraguay (Alto Paraná)

Mar-85

-

14,000

8,577.00

25,604,788

22,560,165

-

-

-

-

Amazonas GT (15)

HPU Balbina

AM

Jan-89

Mar-27

249.75

132.30

145,662

215,313

130.30

301.92

Mar-27

-

TPP Aparecida

AM

Feb-84

Jul-20

282.48

186.00

0

80,839

145.30

125.74

Jul-20

-

TPP Mauá

AM

Apr-73

Jul-20

502.16

179.80

189,713

110,528

98.61

108.59

Jul-20

-

TPP São José

AM

Feb-08

Aug-16

73.40

50.00

0

33,593

-

-

-

-

TPP Flores

AM

Feb-08

Aug-16

124.70

80.00

2

128,879

-

-

-

-

TPP Iranduba

AM

Nov-10

Aug-16

66.6

25

0

33,335

-

-

-

-

(1) Order No. 223 of 01.28.2014 ANEEL declares as unserviceable assets of TPU Rio Madeira.

(2) Order No. 136 of 01.21.2014 ANEEL, recommends the MME extinction of the public service commitment of TPUs Rio Branco I and Rio Branco II.

(3) Authoritative Resolution No. 2,894/2011 transfers TPP Senador Arnon Farias de Mello from Eletronorte to Boa Vista S.A. up to 10 February, 2012. Ordinance No. 318/2014 extends deadline up to the date of effective interconnection of the Isolated System of Boa Vista to the SIN.

(4) The energy assured of block I in TPP Santana is 13.4 Mwmed and of block II is 8.9 Mwmed. MME Ordinance No. 185, of 12/27/2012.

(5) MME Ordinance No. 4 of 01/09/2017 decides to undo the energy contracting from TPP Santarem from January 2017 onwards. MME Ordinance No. 88/2014 and MME Ordinance No.418/2014 were repealed.

(6) MME Ordinance No. 333/2015, emergentially, granted Eletronorte the installation of 20 MW until 2019 or the go-live of the structuring solution. Commercial operation authorized from 04/09/2016 onwards (Order No. 872/2016 - SCG/ANEEL of 04/08/2016)

(7) In response to Official Letter No. 729/2015 SFG/ANEEL, CE PRI 248 of 10/19/2015 establishes the go live dates of HPU's Samuel, Curuá-Uma, Tucuruí I and II and TPP Santana.

(8) Camaçari Plant should be definitely out of service from 08/02/2016 onwards, according to ANEEL Order No.3,247/2016 of 12/13/2016.

(9) We consider the end of operation as being the end of concession, however, according to ANEEL Ordinance No. 3,247 of 12/13/2016, Camaçari plant has suspended its operation from 08/02/2016 onwards.

(10) 175.40 MW average correspond to physical guarantee Simplicio only. The Simplicio Anta complex will have 191.30 MW of assured power when Anta is in commercial operation.

(11) Shared HPU's, but Furnas, through energy purchase contracts, receives the partner portion - considering energy assured and the total generation of each HPU.

(12) The capacity of 500 MW excludes the GUs 3 and 4, which commercial operation is temporarily suspended by ANEEL Order No. 3,263 of 10/19/2012. It includes, however, the capacity of 150MW of GUs 11 and 21 although they are not operating due to a delay in expansion works of the plant.

(13) Extension of the concession requested to ANEEL under request REQ.GCO.P.027.2013, of 07.05.2013. So far, no response from the Agency.

(*) The amounts reported refer to the Company's participation in the project (Governador Jayme Canet Júnior Consortium - 49% Eletrosul)

(14) The B Phase of P. Médici, which is inoperative since 03/01/2017 due to environment issues, considers the installed capacity and the energy assured.

(15) The available power of Mauá BL 4 Plant is 14MW, according to ANEEL Order No. 1,853 / 2016. For HPU Aparecida, the value to be considered refers only to Natural Gas, using 166 MW of Installed Capacity.

                         
                         

II.1.2.1.1 Eletrobras Companies Average price of Sale and Purchase of Energy

2Q17

Eletrobras Companies Average Price(R$)

                      
                     

RCE

243.54

                      

FCE

145.04

                      

Purchase of energy

190.64

                      

 

32

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex III - 2Q17

Operating Information of the Subsidiaries

II.1.2.2 Generation Assets and Generated Energy – Enterprises under Integral Responsibility – O&M - renewed by 12,783/13 law

    

Eletrobras Companies

Enterprise

Location

Beginning of Operation

End of Operation

Installed Capacity

Energy Assured

Generated Energy (MWh)

Quotas – O&M Regime: Law 12,783/2013

FCE - Law 13,182/2015 (2)

(State)

(MW)

(MW Average)

1Q17

2Q17

MW Average

GAG (R$ Million)

RAG (R$ Million)

Amount of new investments recognized by Aneel in GAG in the last adjustment (R$ Million) (1)

MW Average

Average price (R$/MWh)

Eletronorte

HPU Coaracy Nunes

AP

Oct-75

Dec-42

78.00

62.60

135,044

158,044

62.60

-

12.07

-

n/a

n/a

Chesf

Funil

BA

Mar-62

Dec-42

30.00

10.91

4,807

10,156

10.66

4.11

6.14

0.13

0.24

120.79

Pedra

BA

Apr-78

Dec-42

20.01

3.74

7.20

5,374

3.66

2.18

3.85

0.18

0.08

120.79

Araras (1)

CE

Feb-67

Jul-15

4.00

0.03

-

-

-

-

-

-

-

-

Complexo de Paulo Afonso

BA

Jan-55

Dec-42

4,279.60

2,225.00

1,524

1,352,720

2,175.85

169.06

540.59

41.25

49.16

120.79

Luiz Gonzaga (Itaparica)

PE

Feb-88

Dec-42

1,479.60

959.00

687

609,028

937.82

83.38

209.24

4.65

21.19

120.79

Boa Esperança (Castelo Branco)

PI

Jan-70

Dec-42

237.30

143.00

283,513

263,335

139.84

20.91

50.42

11.60

3.16

120.79

Xingó

SE

Apr-94

Dec-42

3,162.00

2,139.00

1,759

1,435,439

2,091.75

148.68

398.75

3.57

47.26

120.79

Furnas

Furnas

MG

Mar-63

Dec-42

1,216.00

598.00

971,441.47

441,010

598.00

67.31

143.01

-

n/a

n/a

Luis Carlos Barreto (Estreito)

SP/MG

Jan-69

Dec-42

1,050.00

495.00

962,145.34

448,532

495.00

59.41

139.46

-

n/a

n/a

Porto Colômbia

MG/SP

Mar-73

Dec-42

320.00

185.00

481,487.24

250,170

185.00

26.52

43.76

-

n/a

n/a

Marimbondo

SP/MG

Apr-75

Dec-42

1,440.00

726.00

1,576,380.71

941,771

726.00

76.99

198.55

-

n/a

n/a

Funil

RJ

Apr-69

Dec-42

216.00

121.00

221,088.99

181,646

121.00

19.61

27.76

-

n/a

n/a

Corumbá I

GO

Apr-97

Dec-42

375.00

209.00

230,575.60

179,984

209.00

29.47

60.53

-

n/a

n/a

Eletronuclear

-

-

-

-

-

-

-

 

-

-

-

-

-

-

Eletrosul

-

-

-

-

-

-

-

 

-

-

-

-

-

-

CGTEE

-

-

-

-

-

-

-

 

-

-

-

-

-

-

Itaipu Binacional

-

-

-

-

-

-

-

 

-

-

-

-

-

-

Amazonas GT

-

-

-

-

-

-

-

 

-

-

-

-

-

-

(1) The assured energy of Araras is 0.03 mW average, according to MME Ordinance No. 58 of 07/30/2012.

                             
                             
                             

II.1.2.3 Generation Assets and Generated Energy – Enterprises under Integral Responsibility renewed by 13,182/15 Law

      

Eletrobras Companies

Enterprise

Location

Beginning of Operation

End of Operation

Installed Capacity

Energy Assured

Energia Gerada (MWh)

RCE

FCE

    

(States)

(MW)

(MW Average)

1Q17

2Q17

MW Average

Average price (R$/MWh)

Contracts and Validity in RCE

MW Average

    

Chesf

Sobradinho

BA

Apr-79

Feb-52

1,050.30

531.00

327

299,374

-

-

-

-

   

Furnas

Itumbiara (1)

GO/MG

Apr-75

Dec-42

2,082.00

1,015.00

934,966

296,426

292.68

294.49

13thLEE2014 - Dec/2019 14thLEE2005 - Dec/2017

688.59

   

(1) Law 13,182 of 11.03.2015, allowed FURNAS to extend the HPU Itumbiara concession provided that it had participation in Southest-Midwest Energy Fund (FESC) and in energy contracts backed by the plant assured energy with consumer units located in Southest-Midwest market, from auctions held by Furnas. Therefore, Furnas will have the HPU Itumbiara concession extended for an additional period up to 30 years.

    

 

33

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex III - 2Q17

Operating Information of the Subsidiaries

II.1.3. Energy Sold

         
           

II.1.3.1 Energy Sold by enterprises not renewed by 12,783/13 Law

    

Company

Buyer

1Q17

2Q17

R$ Million

MWh

R$ Million

MWh

Eletronorte

Eletrobras System

123.94

566,850

122.62

563,362

Others

711.40

5,191,947

618.34

4,444,067

Chesf

Eletrobras System

-

-

-

-

Others

68.30

298,178

242.50

1,701,325

Furnas

Eletrobras System

81.58

317,402

51.37

195,294

Others

966.20

5,025,739

988.93

4,768,075

Eletronuclear

Eletrobras System

34.74

152,755

34.74

154,524

Others

737.26

3,241,747

737.26

3,279,284

Eletrosul

Eletrobras System

0.00

0

0.00

0

Others

106.79

523,294

103.84

505,052

CGTEE

Eletrobras System

78.94

638,020

70.47

688,128

Others

0.00

0

0.00

0

Itaipu Binacional

Eletrobras System

834.01

21,773,552

844.55

19,560,850

Others

113.73

3,644,356

79.06

2,837,603

Amazonas GT

Eletrobras System

110.62

694,023

144.89

752,706

Others

0.00

0

0.00

0

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

           
           

II.1.3.2 Energy Sold by enterprises renewed by 12,783/13 Law – O&M

    

Company

Buyer

1Q17

2Q17

R$ Million

MWh

R$ Million

MWh

Eletronorte

Eletrobras System

0.20

6,932

0.16

6,006

Others

3.74

127,547

4.07

151,795

Chesf

Eletrobras System

27.96

691,970.18

27.86

489,259.39

Others

470.64

12,130,203

328.97

11,216,107

Furnas

Eletrobras System

10.95

396,870

7.90

400,295

Others

204.93

4,656,974

199.65

4,697,161

Eletronuclear

Eletrobras System

-

-

-

-

Others

-

-

-

-

Eletrosul

Eletrobras System

-

-

-

-

Others

-

-

-

-

CGTEE

Eletrobras System

-

-

-

-

Others

-

-

-

-

Itaipu Binacional

Eletrobras System

-

-

-

-

Others

-

-

-

-

Amazonas GT

Eletrobras System

-

-

-

-

Others

-

-

-

-

 

34

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex III - 2Q17

Operating Information of the Subsidiaries

II.1.3.3 CCEE Settlement (Spot and MRE)

      

Company

1Q17

2Q17

R$ Million

MWh

R$ Million

MWh

Eletronorte

214.17

3,783,205.68

260.92

4,385,225

Chesf

45.18

422,419.11

119.27

- 51,559

Furnas

-16.69

-

-26.57

-

Eletronuclear

-

-

-

-

Eletrosul

-2.68

19,902.24

3.80

18,709

CGTEE

36.46

376,614.04

39.06

268,229

Itaipu Binacional

n/a

n/a

n/a

n/a

Amazonas GT

23.13

-33,884.28

46.85

- 163,282.32

 

35

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex III - 2Q17

Operating Information of the Subsidiaries

II.1.4 Energy purchased for Resale

        

Company

Buyer

1Q17

2Q17

R$ Million

MWh

R$ Million

MWh

Eletronorte

Eletrobras System

-

-

-

-

Others

62.85

657,956

20.43

263,590

Chesf

Eletrobras System

-

-

-

-

Others

64.21

356,390

65.19

362,126

Furnas

Eletrobras System

-

-

-

-

Others

152.17

840,450

179.57

956,330

Eletronuclear

Eletrobras System

n/a

n/a

n/a

n/a

Others

n/a

n/a

n/a

n/a

Eletrosul

Eletrobras System

66.57

335,277

99.24

552,430

Others

-

-

-

-

CGTEE

Eletrobras System

53.02

291,735

54.01

294,840

Others

-

-

-

-

Itaipu Binacional

Eletrobras System

n/a

n/a

n/a

n/a

Others

n/a

n/a

n/a

n/a

Amazonas GT

Eletrobras System

-

-

-

-

Others

-

-

-

-

 

36

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex III - 2Q17

Operating Information of the Subsidiaries

II.1.5 Average Rate – R$/MWh

  
     

II.1.5.1 Enterprises not renewed by 12,783/13 Law

 

Eletrobras Companies

1Q17

2Q17

Eletronorte

145.06

147.97

Chesf

135.70

155.00

Furnas

196.10

209.59

Eletronuclear

227.43

224.82

Eletrosul

204.06

205.60

CGTEE

239.23

241.93

Itaipu Binacional (1)

22.60

22.60

Amazonas GT

159.38

192.50

(1) Amounts in U$/KW.

 

 

 

 

 

 

 

 

     

II.1.5.2 Enterprises renewed by 12,783/13 Law – O&M

Eletrobras Companies

2Q17

2Q17

Eletronorte

29.30

26.78

Chesf

30.80

30.18

Furnas

42.72

40.72

Eletronuclear

n/a

n/a

Eletrosul

n/a

n/a

CGTEE

n/a

n/a

Itaipu

n/a

n/a

Amazonas GT

n/a

n/a

 

37

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex III - 2Q17

Operating Information of the Subsidiaries

II.1.6 Fuel used by Electric Energy Production

      

Eletrobras Companies

Type

Unit

1Q17

2Q17

Amount

R$ Million

Amount

R$ Million

Eletronorte

Special Diesel Oil

Litre

-

-

-

-

Chesf

Diesel Oil

Litre

-

-

-

-

Gas

m3

-

-

-

-

Furnas

Special Diesel Oil

Litre

-

-

-

-

Fuel Oil B1

Ton

-

-

-

-

Diesel Oil

Litre

-

-

-

-

Gas

m3

173,775,939

149.83

78,342,917

83.55

Eletronuclear

Uranium

kg

97,186

126.35

98,888

103.35

Eletrosul

n/a

n/a

n/a

n/a

n/a

n/a

CGTEE

Coal

Ton

366,963

26.32

384,239

27.56

Fuel Oil

kg

4,561,513

7.49

2,747,420

4.77

Diesel Oil

Litre

37,800

0.08

22,576

0.06

Quicklime

kg

12,086,310

9.44

18,917,210

14.38

Itaipu Binacional

n/a

n/a

n/a

n/a

n/a

n/a

Amazonas GT

Diesel Oil

Litre

-

-

-

-

gas

m3

-

-

10,734,845

15,876,836

 

38

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex III - 2Q17

Operating Information of the Subsidiaries

 

III. Transmission – Assets under Integral Responsibility

            
                     

III.1 Transmission Lines Extension

                
                     

III.1.1.1 Transmission Lines Extension – Enterprises not renewed by 12,783/13 Law - Km

        

Eletrobras Companies

765 KV

600 KV

525 KV

500 KV

440 KV

345 KV

230 KV

138 KV

<138 KV

Total

Eletronorte

-

-

-

-

-

-

1,767

-

-

1,767

Chesf

-

-

-

-

-

-

1,408

-

-

1,408

Furnas

-

-

-

844

-

161

116

393

-

1,514

Eletrosul

-

-

1,047

-

-

-

455

50

12

1,565

Amazonas GT

-

-

-

-

-

-

390

-

-

390

Total

-

-

1,047

844

-

161

4,135

443

12

6,643

                     
                     

III.1.1.2 Transmission Lines Extension – Enterprises renewed by 12,783/13 Law - Km

        

Eletrobras Companies

765 KV

600 KV

525 KV

500 KV

440 KV

345 KV

230 KV

138 KV

<138 KV

Total

Eletronorte

-

-

-

3,243

-

-

5,605

959

203

10,011

Chesf

-

-

-

5,373

-

-

12,822

463

311

18,968

Furnas

2,698

1,612

-

4,005

-

6,145

1,863

2,121

165

18,608

Eletrosul

-

-

2,722

-

-

-

4,800

1,848

56

9,426

Amazonas GT

-

-

-

-

-

-

-

-

-

-

Total

2,698

1,612

2,722

12,621

-

6,145

25,090

5,391

735

57,013

                     
                     

III.2 Transmission Losses - %

                    

Empresa Eletrobras

1Q17

2Q17

                

Eletronorte

0.96%

1.37%

                

Chesf

2.62%

2.86%

                

Furnas

2.12%

1.87%

                

Eletrosul

1.49%

1.38%

                

Amazonas GT

0.15%

0.13%

                

 

 

 

39

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex III - 2Q17

Operating Information of the Subsidiaries

III.3 Transmission Lines

            
               

III.3.1 Transmission Lines – Enterprises not affected by 12,783 Law

          

Eletrobras Companies

From-To

Extension (km)

Tension (kV)

Beginning of Operation

End of Concession

AAR on 06.30.17(R$ Million)(1)

Readjustment Index

Eletronorte

São Luiz II / São Luiz III

35.94

230

May-10

Mar-38

1.74

9.32%

Ribeiro Gonçalves / Balsas

95.00

230

Dec-11

Jan-39

2.40

9.32%

Porto Velho / Abunã - C2 (1)

188.00

230

Feb-14

Nov-39

12.59

9.32%

Abunã / Rio Branco - C2

298.00

230

Jan-14

Nov-39

19.53

9.32%

Lechuga / Jorge Teixeira – C1 (2)

29.54

230

Feb-14

Jul-40

2.40

-5.23%

Lechuga / Jorge Teixeira – C2 (2)

29.54

230

Feb-14

Jul-40

2.40

-5.23%

Lechuga / Jorge Teixeira – C3

29.54

230

Mar-15

May-42

2.24

9.32%

Coletora Porto Velho / Porto Velho – C1

22.00

230

Aug-15

Feb-39

1.00

9.32%

Coletora Porto Velho / Porto Velho – C2

22.00

230

Aug-15

Feb-39

1.00

9.32%

Samuel / Ariquemes - C3

154.44

230

Dec-15

Nov-39

9.72

9.32%

Ariquemes / Ji-Paraná - C3 (1)

165.00

230

Mar-16

Nov-39

11.62

9.32%

Ji-Paraná / Pimenta Bueno - C3

119.20

230

May-16

Nov-39

8.37

9.32%

Pimenta Bueno / Vilhena - C3

161.00

230

Dec-15

Nov-39

10.75

9.32%

Utinga - Miramar - C1

15.70

230

Aug-15

Dec-42

0.91

9.40%

Utinga - Miramar - C2

15.70

230

Aug-15

Dec-42

0.91

9.40%

Samuel / Porto Velho - C3

42.40

230

Oct-15

Nov-39

3.36

9.32%

Jauru / Vilhena - C3

343.60

230

Nov-15

Nov-39

21.43

9.32%

Chesf

Ibicoara-Brumado, C1

94.50

230

Mar-12

Jun-37

9.09

9.32%

Milagres-Coremas, C2

119.80

230

Jun-09

Mar-35

7.64

9.32%

Milagres-Tauá, C1

208.10

230

Dec-07

Mar-35

17.68

9.32%

Paulo Afonso III- Zebu II, C1

5.40

230

Aug-12

Aug-39

19.77

9.32%

Paulo Afonso III- Zebu II, C2

5.40

230

Aug-12

Aug-39

Paraiso-Açu II, C2

132.80

230

Sep-10

Jun-37

11.39

9.32%

Picos-Tauá II, C1

183.20

230

Feb-13

Jun-37

Pirapama II-Suape II, C1

20.90

230

Dec-12

Jan-39

19.99

9.32%

Pirapama II-Suape II, C2

20.90

230

Dec-12

Jan-39

Suape III-Suape II, C1

3.60

230

Dec-12

Jan-39

Suape III-Suape II, C2

3.60

230

Dec-12

Jan-39

C. Mirim II-João Câmara II C1

74.50

230

Feb-14

Nov-40

9.77

9.32%

Extremoz II-C. Mirim II C1

31.40

230

Feb-14

Nov-40

Jardim/Penedo, C1

110.00

230

Mar-14

Mar-38

1.10

9.32%

B. Jesus da Lapa II – Igaporã II

115.00

230

May-14

Nov-40

5.91

9.32%

Acaraú II-Sobral III, C2

91.30

230

Sep-15

Nov-40

6.57

9.32%

Igaporã II-Igaporã III,C1

5.40

230

out/15

Jun-42

9.07

9.32%

Igaporã II-Igaporã III,C2

5.40

230

out/15

Jun-42

Igaporã III-Pindaí II,C1

49.50

230

out/15

Jun-42

Paraiso-Lagoa Nova II, C1

65.40

230

dez/16

Oct-41

3.98

9.32%

Ceará Mirim II-Touros II

61.50

230

mai/17

Jun-42

2.38

9.32%

Furnas

Ibiúna - Bateias Circuito 1

332.00

500

Mar-03

May-31

281.82

IGPM

Ibiúna - Bateias Circuito 2

332.00

500

Mar-03

May-31

TL Bom Despacho 3 – Ouro Preto 2 (4) (5)

180.00

500

Feb-16

Jan-39

9.87

IPCA

Tijuco Preto - Itapeti 3

21.00

345

Jan-13

Apr-36

18.50

IPCA

Tijuco Preto - Itapeti 4

21.00

345

Jan-13

Apr-36

Itapeti - Nordeste

29.00

345

Dec-14

Apr-36

Campos - Macaé 3

90.00

345

Jun-10

Mar-35

18.66

IGPM

Pirineus - Xavantes C2 (11)

50.00

230

Mar-16

Dec-41

-

-

Manso – Nobres (3) (6)

66.00

230

Nov-00

Feb-35

-

-

Manso – Nobres (3) (7)

70.00

138

Aug-99

Feb-35

-

-

Batalha – Paracatu (3)

85.00

138

Sep-13

Aug-41

-

-

Simplício - Rocha Leão 1 (3)

119.00

138

Jun-13

Aug-41

-

-

Simplício - Rocha Leão 2 (3)

119.00

138

Jun-13

Aug-41

-

-

Eletrosul

Abdon Batista/Biguaçu

234.80

525

Sep-06

Mar-35

48.37

IGPM

Abdon Batista/Campos Novos

35.00

525

Sep-06

Mar-35

8.46

IGPM

Biguaçu / Blumenau

88.00

525

Sep-06

Mar-35

18.63

IGPM

Salto Santiago/Ivaiporã

168.50

525

Oct-05

Feb-34

35.46

IGPM

Ivaiporã/Cascavel Oeste

203.40

525

Oct-05

Feb-34

38.79

IGPM

Campos Novos(SC)/Nova S. Rita(RS)

257.43

525

May-09

Apr-36

32.39

IPCA

Candiota - Melo

60.00

525

Jul-15

Feb-40

(8)

IPCA

Presidente Médici-Candiota

2.80

230

Jul-15

Feb-40

(8)

IPCA

Presidente Médice/Santa Cruz

237.40

230

Jan-10

Mar-38

5.17

IPCA

Monte Claro /Garibaldi

32.70

230

Sep-13

Oct-40

2.08

IPCA

Monte Claro/Nova Prata 2

11.00

230

Sep-04

Dec-42

0.42

IPCA

Passo Fundo/Nova Prata 2

11.00

230

Nov-92

Dec-42

0.42

IPCA

Cascavel Oeste / Guaíra (melhorias)

-

230

Mar-13

Dec-42

0.06

IPCA

Biguaçu / Jorge Lacerda B (melhorias)

-

230

Aug-14

Dec-42

0.09

IPCA

Foz do Chapecó/Xanxerê1

77.60

230

Oct-10

Jun-41

(9)

IPCA

Foz do Chapecó/Xanxerê2

77.60

230

Oct-10

Jun-41

(9)

IPCA

Gaspar/Palhoça

2.50

230

Oct-16

Dec-42

0.88

IPCA

Gaspar/Blumenau

2.50

230

Oct-16

Dec-42

0.98

IPCA

Palhoça/Palhoça Pinheira

9.50

138

Feb-16

Dec-42

0.15

IPCA

Palhoça Pinheira/Imbituba

9.50

138

Feb-16

Dec-42

0.15

IPCA

Joinville Santa Catarina / Picarras

1.00

138

Oct-99

Dec-42

0.23

IPCA

Joinville / Joinville Santa Catarina

1.06

138

Oct-99

Dec-42

 

 

Araquari/Joinville GM

0.10

138

May-12

Dec-42

0.25

IPCA

Joinville/Joinville GM

0.10

138

May-12

Dec-42

0.10

IPCA

Ivinhema2/Nova Andradina

9.77

138

Jul-16

Dec-42

0.13

IPCA

Nova Andradina - Porto Primavera

12.23

138

Jul-16

Dec-42

0.71

IPCA

Ivinhema/Ivinhema 2

3.50

138

Jan-16

Jan-44

0.33

IPCA

Ivinhema2/Nova Andradina

3.50

138

Jan-16

Jan-44

0.44

IPCA

Biguaçu / Tijucas (melhorias)

-

138

Nov-12

Dec-42

0.02

IPCA

Conversora de Uruguaiana / Passo de Los Libres - 132 kV

12.50

132

Sep-94

Jul-21

0.35

IPCA

Amazonas G&T

Balbina–Cristiano Rocha

154.89

230

Nov-06

Mar-27

(10)

0.06

Ramal de Transmissão–Presidente Figueiredo

0.12

230

Sep-08

Mar-27

(10)

0.06

Balbina – Lechuga

159.29

230

Apr-15

Mar-27

(10)

0.06

Cristiano Rocha - Lechuga

5.44

230

Jul-13

Mar-27

(10)

0.06

Manaus - Lechuga -Circuito1

19.73

230

Jul-13

Mar-27

(10)

0.06

Manaus - Lechuga -Circuito2

19.70

230

Apr-15

Mar-27

(10)

0.06

Jorge Teixeira - Mauá 3 Circuito 1

13.73

230

May-14

Feb-44

(10)

0.06

Jorge Teixeira - Mauá 3 Circuito 2

13.73

230

May-14

Feb-44

(10)

0.06

Balbina – Balbina – Circuito 1

0.59

230

Feb-89

Mar-27

(10)

0.06

Balbina – Balbina – Circuito 2

0.64

230

Apr-89

Mar-27

(10)

0.06

Balbina – Balbina – Circuito 3

0.64

230

Apr-89

Mar-27

(10)

0.06

Balbina – Balbina – Circuito 4

0.68

230

Sep-89

Mar-27

(10)

0.06

Balbina – Balbina – Circuito 5

0.68

230

Jul-89

Mar-27

(10)

0.06

(1) These substations were added because theses amounts are from Concession 058/2001.

(2) Includes RBNIA which started operation in this cycle.

(3) These transmission assets are not part of the core network. They are connecting branches of the generation enterprises. The concession contracts are the same as those of the plants: a) Manso-Nobres: CT 010.2000; B) Battle-Paracatu: CT 002.2006; C) Simplício-Rocha León 1 and 2: CT 003.2006.

(4) AAR amounts considered were established by ReH 2098/2016 for the cycle 2016/2017.

(5) TL Bom Despacho 3-Ouro Preto 2, in 500 kV (CC 003/2009): The total amount of the AAR cycle 2016/2017 is R$ 10.960.934,33, and Furnas is receiving the partial AAR in the Amount of R$ 9.872.839,01 related to assets that entered into commercial operation.

(6) The 230kV TL is in the concession contract of HPU Manso, not having, for this reason, its own AAR. As it belongs to a generation contract, Furnas has only 70% of the line.

(7) TL 138kV was built to supply the residential village, at the time of HPU implementation. However, the population once supplied still needed to be served. Unsuccessfully, an attempt to transfer this TL to Cemat was done. Furnas maintains this TL but there is no associated revenue.

(8) Binational enterprise (Brazil-Uruguay Interconnection), with partial assignment of rights between Eletrobras and Eletrosul. The annual pass-through of revenue is R$ 19.5 million, readjusted in March of each year.

(9) Non-onerous transfer of assets of Foz do Chapecó Energia S.A.

(10) Waiting for authorization from ANEEL to receive AAR.

(11) At the moment Furnas is not receiving AAR, regarding CC 014/2011 - LT Xavantes-Pirineus, because it does not have a Release Term issued by the ONS for such undertaking.

 

 

40

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex III - 2Q17

Operating Information of the Subsidiaries

III.3.2 Transmission Lines – Enterprises renewed under terms of 12,783 law

Eletrobras Companies

From-To

Extension (km)

Tension (kV)

Beginning of Operation

End of Concession

AAR on 06.30.2017(R$ Million)(1)

Readjustment Index

Eletronorte

Boa Vista- Santa Elena

190.20

230

Jun-01

Dec-42

Isolated System. No AAR.

Isolated System. No AAR.

Coaracy Nunes - Santana - C1

108.00

138

Oct-75

Dec-42

Isolated System. No AAR.

Isolated System. No AAR.

Coaracy Nunes - Santana - C2

109.00

138

Feb-05

Dec-42

Isolated System. No AAR.

Isolated System. No AAR.

Santana – Portuária

4.00

138

Apr-96

Dec-42

Isolated System. No AAR.

Isolated System. No AAR.

Coaracy Nunes - Tartarugalzinho

87.00

138

Jun-00

Dec-42

Isolated System. No AAR.

Isolated System. No AAR.

Santana - Macapá II

20.00

69

Nov-96

Dec-42

Isolated System. No AAR.

Isolated System. No AAR.

Santana – Equatorial

13.00

69

Aug-00

Dec-42

Isolated System. No AAR.

Isolated System. No AAR.

Tartarugalzinho – Calçoene

130.00

69

Dec-01

Dec-42

Isolated System. No AAR.

Isolated System. No AAR.

Tartarugalzinho – Amapá

17.00

69

Feb-02

Dec-42

Isolated System. No AAR.

Isolated System. No AAR.

Santana - Santa Rita

12.60

69

Dec-07

Dec-42

Isolated System. No AAR.

Isolated System. No AAR.

Equatorial - Santa Rita

5.09

69

Sep-08

Dec-42

Isolated System. No AAR.

Isolated System. No AAR.

Colinas – Miracema

173.97

500

Mar-99

Dec-42

8.42

9.40%

Imperatriz – Colinas

342.60

500

Mar-99

Dec-42

14.13

9.40%

Imperatriz – Marabá - C1

181.09

500

Apr-81

Dec-42

7.93

9.40%

Imperatriz – Marabá - C2

181.82

500

Mar-88

Dec-42

7.77

9.40%

Tucuruí – Marabá – C1

222.14

500

Oct-81

Dec-42

9.13

9.40%

Tucuruí – Marabá – C2

221.70

500

Feb-88

Dec-42

9.31

9.40%

Tucuruí - Vila do Conde

327.10

500

Dec-81

Dec-42

12.01

9.40%

Tucuruí (Usina) - Tucuruí (Se)

10.71

500

nov/84 a mai/05

Jul-24

Exclusive use of Eletronorte Generation

-

Pres. Dutra - Boa Esperança

205.39

500

Jan-00

Dec-42

8.41

9.40%

Imperatriz - Pres. Dutra - C1

386.60

500

Oct-82

Dec-42

14.89

9.40%

Imperatriz - Pres. Dutra - C2

385.30

500

Jan-00

Dec-42

14.79

9.40%

Miranda II - S.Antonio dos Lopes

142.60

500

Nov-10

Dec-42

1.96

-

S.Antonio dos Lopes - Pres. Dutra

52.90

500

Nov-10

Dec-42

5.51

9.40%

Miranda II - Pres. Dutra – C2

195.80

500

Mar-86

Dec-42

7.52

9.40%

São Luiz II - Miranda II – C1

106.80

500

Jul-84

Dec-42

4.31

9.40%

São Luiz II - Miranda II – C2

106.80

500

Mar-86

Dec-42

4.31

9.40%

Altamira – Rurópolis (2)

-

230

Oct-88

Dec-42

6.00

9.40%

Altamira – Transamazônica

184.62

230

Oct-88

Dec-42

0.73

9.40%

Transamazônica – Rurópolis

145.40

230

Oct-88

Dec-42

0.73

9.40%

Guamá - Utinga - C1

19.40

230

Dec-81

Dec-42

0.60

9.40%

Guamá - Utinga - C2

19.40

230

Dec-81

Dec-42

0.60

9.40%

Tucuruí – Altamira (2)

317.60

230

Jun-98

Dec-42

5.89

9.40%

Utinga - Castanhal

69.27

230

Dec-94

Dec-42

2.31

9.40%

Castanhal - Santa Maria

25.04

230

Dec-94

Dec-42

1.33

9.40%

Vila do Conde - Guamá - C1

49.30

230

Apr-81

Dec-42

0.88

9.40%

Vila do Conde - Guamá - C2

49.30

230

Dec-82

Dec-42

0.84

9.40%

Marabá - Carajás

145.00

230

Oct-04

Dec-42

2.13

9.40%

Carajás – Integradora - C1

83.00

230

Aug-08

Dec-42

Line not transferred to Eletronorte yet

Line not transferred to Eletronorte yet

Carajás – Integradora - C2

85.35

230

Aug-13

Dec-42

0.72

9.40%

Carajás – Integradora - C3

85.35

230

Aug-13

Dec-42

0.64

9.40%

Imperatriz - Porto Franco

110.10

230

Oct-94

Dec-42

1.80

9.40%

São Luiz II - Miranda II

105.30

230

Nov-02

Dec-42

1.90

9.40%

São Luiz II - São Luiz I - C1

18.60

230

Jan-83

Dec-42

0.61

9.40%

São Luiz II - São Luiz I – C2

19.00

230

Sep-88

Dec-42

0.61

9.40%

Miranda II - Peritoró

94.20

230

Dec-02

Dec-42

1.75

9.40%

Pres. Dutra - Peritoró

115.00

230

Mar-03

Dec-42

1.75

9.40%

Peritoró - Coelho Neto

223.00

230

Jul-06

Dec-42

3.31

9.40%

Coelho Neto - Teresina

127.10

230

Sep-06

Dec-42

1.89

9.40%

São Luiz II - UTE São Luiz

0.05

230

Jan-82

Dec-42

-

-

Barra Peixe – Rondonópolis – C1

217.00

230

Oct-97

Dec-42

3.16

9.40%

Rondonópolis - Coxipó - C1

187.80

230

Sep-88

Dec-42

3.11

9.40%

Rondonópolis - Coxipó - C2

187.80

230

Jul-84

Dec-42

3.06

9.40%

Coxipó - Nobres

112.41

230

Sep-96

Dec-42

2.47

9.40%

Nobres – Nova Mutum - C1

104.57

230

Sep-96

Dec-42

2.00

9.40%

Nova Mutum – Lucas do Rio Verde - C1

93.80

230

Sep-96

Dec-42

1.41

9.40%

Lucas do Rio Verde - Sorriso C-1

52.50

230

Sep-96

Dec-42

0.86

9.40%

Sinop - Sorriso C-1

74.78

230

Sep-96

Dec-42

0.90

9.40%

Barra Peixe – Rondonópolis – C2

216.79

230

Mar-08

Dec-42

3.51

9.40%

Rio Verde (C. Magalhães) – Rondonópolis

177.83

230

Jul-83

Dec-42

0.50

9.40%

Jauru - Coxipó - C1

-

230

Jun-03

Dec-42

PORTIONED

0.00%

Jauru - Várzea Grande - C1 (2)

336.89

230

Jun-03

Dec-42

5.19

9.40%

Várzea Grande - Coxipó - C1 (2)

28.80

230

Jun-03

Dec-42

1.20

9.40%

Jauru - Coxipó - C2

-

230

Jun-03

Dec-42

PORTIONED

0.00%

Jauru - Várzea Grande - C2 (2)

336.89

230

Jun-03

Dec-42

4.79

9.40%

Várzea Grande - Coxipó - C2

28.80

230

Jun-03

Dec-42

0.96

9.40%

Abunã - Rio Branco –C1

302.00

230

Nov-02

Dec-42

4.64

9.40%

Ariquemes - Jarú

83.82

230

Sep-94

Dec-42

1.76

9.40%

Jarú - Ji-Paraná

80.69

230

Sep-94

Dec-42

1.80

9.40%

Samuel - Ariquemes

151.60

230

Aug-94

Dec-42

2.35

9.40%

Samuel - Porto Velho – C1

40.55

230

Jul-89

Dec-42

0.75

9.40%

Samuel - Porto Velho – C2

40.55

230

Jul-89

Dec-42

0.75

9.40%

Samuel (Usina) - Samuel (SE)

2.85

230

Jul-89

Sep-29

Exclusive use of Eletronorte Generation

-

Porto Velho - Abunã

188.00

230

May-02

Dec-42

3.07

9.40%

Ji-Paraná - Pimenta Bueno

117.80

230

Jun-08

Dec-42

2.08

9.40%

Pimenta Bueno – Vilhena

160.20

230

Oct-08

Dec-42

2.71

9.40%

Tucuruí-Vila - Cametá

214.21

230

Aug-98

Dec-42

2.00

9.40%

Curuá-Una - Tapajós-Celpa

68.80

230

Jan-06

Jul-28

Exclusive use of Eletronorte Generation

(3)

Coxipó - São Tadeu

44.17

138

Jul-81

Dec-42

1.74

9,40%

São Tadeu - Jaciara

77.92

138

Jul-81

Dec-42

Jaciara - Rondonopolis-Cemat

70.00

138

Jul-81

Dec-42

Couto Magalhães - Rondonopolis-Cemat

176.00

138

Apr-81

Dec-42

1.64

-

Tucuruí - Tucuruí Vila - C2

2.30

69

Jul-97

Dec-42

-

-

Tucuruí - Tucuruí Vila - C1

-

69

Jan-00

Jan-00

-

-

Tucuruí (Usina) - Tucuruí (SS) (1)

1.40

69

Jan-80

Dec-42

Exclusive use of Eletronorte Generation

-

Tucuruí (Usina) - Tucuruí (SS) (1)

1.40

69

Dec-85

Dec-42

Exclusive use of Eletronorte Generation

-

Chesf

Angelim II-Pau Ferro, C1

219.40

500

Aug-77

Dec-42

(3)

9.32%

Recife II-Pau Ferro, C1

114.50

500

Aug-77

Dec-42

(3)

9.32%

Angelim II-Recife II, C2

170.70

500

Mar-80

Dec-42

(3)

9.32%

Jardim-Camaçari IV, C1

249.60

500

May-00

Dec-42

(3)

9.32%

Camaçari II-Camaçari IV, C1

0.30

500

Nov-12

Dec-42

(3)

9.32%

Garanhuns II-Angelim II, C1

13.20

500

Feb-77

Dec-42

(3)

9.32%

L. Gonzaga-Garanhuns II, C1

238.70

500

Feb-77

Dec-42

(3)

9.32%

L. Gonzaga-Milagres, C1

230.80

500

Feb-02

Dec-42

(3)

9.32%

L. Gonzaga-Olindina, C1

248.60

500

May-76

Dec-42

(3)

9.32%

Luiz Gonzaga-Sobradinho, C1

290.60

500

Oct-79

Dec-42

(3)

9.32%

Messias-Suape II, C1

176.60

500

Dec-98

Dec-42

(3)

9.32%

Suape II-Recife II, C1

45.40

500

Dec-98

Dec-42

(3)

9.32%

Milagres-Quixada, C1

268.00

500

Sep-03

Dec-42

(3)

9.32%

Olindina-Camacari II, C1

147.20

500

Oct-76

Dec-42

(3)

9.32%

Olindina-Camacari II, C2

146.90

500

Sep-78

Dec-42

(3)

9.32%

P.Afonso IV-Angelim II, C2

221.50

500

Jul-79

Dec-42

(3)

9.32%

P.Afonso IV-Olindina, C2

212.80

500

Jun-78

Dec-42

(3)

9.32%

P.Afonso IV-L. Gonzaga, C1

37.40

500

Oct-79

Dec-42

(3)

9.32%

P.Afonso IV-Xingo, C1

53.80

500

Feb-93

Dec-42

(3)

9.32%

Pres.Dutra II-Teresina II, C1

207.90

500

May-00

Dec-42

(3)

9.32%

Pres.Dutra II-Teresina II, C1mo

207.70

500

Apr-03

Dec-42

(3)

9.32%

Quixada-FortalezaII, C1

136.50

500

Sep-03

Dec-42

(3)

9.32%

Sobral III-Pecem II, C1

176.60

500

May-00

Dec-42

(3)

9.32%

Pecem II-Fortaleza II, C1

73.10

500

May-00

Dec-42

(3)

9.32%

S.J.Piaui-B.Esperanca, C1

233.50

500

Dec-80

Dec-42

(3)

9.32%

Sobradinho-S.J.Piaui, C1

211.00

500

Dec-80

Dec-42

(3)

9.32%

Sobradinho-Luiz Gonzaga, C2

316.00

500

Jun-88

Dec-42

(3)

9.32%

Teresina II-Sobral III, C1

334.20

500

May-00

Dec-42

(3)

9.32%

Plant Luiz Gonzaga-L.Gonzaga, C1

0.60

500

May-79

Dec-42

(3)

9.32%

Plant Luiz Gonzaga-L.Gonzaga, C2

0.60

500

May-79

Dec-42

(3)

9.32%

Plant Luiz Gonzaga-L.Gonzaga, C3

0.60

500

May-79

Dec-42

(3)

9.32%

Plant IV-P.Afonso IV, C1

0.60

500

Dec-79

Dec-42

(3)

9.32%

Plant IV-P.Afonso IV, C2

0.60

500

May-80

Dec-42

(3)

9.32%

Plant IV-P.Afonso IV, C3

0.60

500

Oct-80

Dec-42

(3)

9.32%

Plant IV-P.Afonso IV, C4

0.60

500

Jul-81

Dec-42

(3)

9.32%

Plant IV-P.Afonso IV, C5

0.60

500

Dec-81

Dec-42

(3)

9.32%

Plant IV-P.Afonso IV, C6

0.60

500

May-83

Dec-42

(3)

9.32%

Plant Sobradinho-Sobradinho, C1

0.40

500

Oct-79

Dec-42

(3)

9.32%

Plant Sobradinho-Sobradinho, C2

0.30

500

Oct-79

Dec-42

(3)

9.32%

Plant Sobradinho-Sobradinho, C3

0.30

500

Oct-79

Dec-42

(3)

9.32%

Plant Xingo – Xingo, C1

0.90

500

Oct-95

Dec-42

(3)

9.32%

Plant Xingo – Xingo, C2

0.90

500

Oct-95

Dec-42

(3)

9.32%

Plant Xingo – Xingo, C3

0.90

500

Oct-95

Dec-42

(3)

9.32%

Plant.Xingo.- Xingo, C4

0.90

500

Oct-95

Dec-42

(3)

9.32%

Plant Xingo – Xingo, C5

0.80

500

Mar-94

Dec-42

(3)

9.32%

Plant Xingo – Xingo, C6

0.80

500

Nov-94

Dec-42

(3)

9.32%

Xingo-Jardim, C1

159.80

500

May-00

Dec-42

(3)

9.32%

Xingo-Messias, C1

219.00

500

Feb-93

Dec-42

(3)

9.32%

Angelim-Messias, C1

78.90

230

Apr-77

Dec-42

(3)

9.32%

Angelim-Messias, C2

78.50

230

Oct-76

Dec-42

(3)

9.32%

Angelim-Messias, C3

79.10

230

Aug-86

Dec-42

(3)

9.32%

Angelim-Ribeirão, C1

115.70

230

Jan-53

Dec-42

(3)

9.32%

Angelim-Recife II, C2

171.70

230

Jan-67

Dec-42

(3)

9.32%

Angelim-Recife II, C3

171.70

230

Jan-61

Dec-42

(3)

9.32%

Angelim-Tacaimbó, C1

63.90

230

Mar-63

Dec-42

(3)

9.32%

Angelim-Tacaimbó, C2

64.10

230

Mar-73

Dec-42

(3)

9.32%

Angelim-Tacaimbó, C3

65.70

230

Jun-98

Dec-42

(3)

9.32%

Arapiraca III–Rio Largo II, C1

124.70

230

Jan-98

Dec-42

(3)

9.32%

Arapiraca III–Penedo, C1

89.60

230

Jan-98

Dec-42

(3)

9.32%

Boa Esperança-Teresina, C1

198.00

230

Mar-70

Dec-42

(3)

9.32%

Boa Esperança-Teresina, C2

198.00

230

Dec-81

Dec-42

(3)

9.32%

Bongi-Açonorte, C1

6.00

230

Aug-76

Dec-42

(3)

9.32%

B.Jesus da Lapa-Barreiras, C1

233.50

230

Dec-90

Dec-42

(3)

9.32%

Banabuiu-Fortaleza, C1

177.20

230

Oct-65

Dec-42

(3)

9.32%

Banabuiu-Fortaleza, C2

176.00

230

Jul-78

Dec-42

(3)

9.32%

Aquiraz II-Banabuiu, C1

181.80

230

Aug-78

Dec-42

(3)

9.32%

Aquiraz II-Fortaleza, C1

30.10

230

Aug-78

Dec-42

(3)

9.32%

Banabuiu-Mossoro II, C1

177.20

230

Jul-03

Dec-42

(3)

9.32%

Banabuiu-Mossoro II, C2

177.20

230

Apr-16

Dec-42

(3)

9.32%

Banabuiu-Russas II, C1

110.40

230

May-71

Dec-42

(3)

9.32%

Bom Nome-Milagres, C1

83.70

230

Sep-61

Dec-42

(3)

9.32%

Bom Nome-Milagres, C2

84.10

230

Dec-74

Dec-42

(3)

9.32%

Bom Nome-Milagres, C3

83.90

230

Sep-79

Dec-42

(3)

9.32%

Cauipe-Sobral, C1

177.40

230

Nov-73

Dec-42

(3)

9.32%

Cicero Dantas-Catu, C1

200.70

230

Mar-68

Dec-42

(3)

9.32%

Cicero Dantas-Catu, C2

201.30

230

Apr-72

Dec-42

(3)

9.32%

C. Grande II - C. Grande III, C1

10.60

230

Oct-99

Dec-42

(3)

9.32%

C. Grande II - C. Grande III, C2

10.60

230

Oct-02

Dec-42

(3)

9.32%

Campina Grande-Coteminas, C1

2.50

230

Oct-99

Dec-42

(3)

9.32%

Campina Grande-Goianinha, C1

99.30

230

Feb-70

Dec-42

(3)

9.32%

C. Grande III – Extremoz II C1

191.40

230

Oct-99

Dec-42

(3)

9.32%

Campina Grande III-Natal III, C1

175.80

230

Oct-02

Dec-42

(3)

9.32%

Natal III-Natal II, C1

11.60

230

Oct-99

Dec-42

(3)

9.32%

Natal III-Natal II, C2

11.60

230

Oct-02

Dec-42

(3)

9.32%

Campina Grande II-Paraiso, C1

118.10

230

May-79

Dec-42

(3)

9.32%

Campina Grande II-Paraiso, C2

119.00

230

Apr-79

Dec-42

(3)

9.32%

Camaçari-Caraíba Metais, C1

3.20

230

Feb-82

Dec-42

(3)

9.32%

Camaçari-Cqr, C1

7.20

230

May-92

Dec-42

(3)

9.32%

Camaçari IV-Cotegipe, C1

22.90

230

Jun-70

Dec-42

(3)

9.32%

Camaçari-Cotegipe, C2

23.50

230

Oct-76

Dec-42

(3)

9.32%

Camaçari-Gov.Mangabeira, C1

83.70

230

Sep-82

Dec-42

(3)

9.32%

Camaçari-Gov.Mangabeira, C2

83.70

230

Sep-82

Dec-42

(3)

9.32%

Camaçari IV-Jacaracanga, C1

19.20

230

Jul-77

Dec-42

(3)

9.32%

Camaçari IV-Jacaracanga, C2

19.20

230

Mar-77

Dec-42

(3)

9.32%

Camaçari-Matatu, C1

47.00

230

Aug-53

Dec-42

(3)

9.32%

Camaçari IV-Pituaçu, C1

39.20

230

Oct-84

Dec-42

(3)

9.32%

Camaçari-Pituaçu, C2

39.20

230

Jan-02

Dec-42

(3)

9.32%

Cotegipe-Jacaracanga, C1

15.20

230

Dec-71

Dec-42

(3)

9.32%

Cotegipe-Matatu, C1

30.00

230

May-77

Dec-42

(3)

9.32%

Catu-Camaçari, C1

25.00

230

Jun-70

Dec-42

(3)

9.32%

Catu-Camaçari, C2

25.00

230

Aug-53

Dec-42

(3)

9.32%

Catu-Gov.Mangabeira, C1

77.20

230

Aug-67

Dec-42

(3)

9.32%

Catu-Itabaianinha, C1

143.90

230

Aug-53

Dec-42

(3)

9.32%

Funil-Itapebi, C1

198.10

230

Jul-90

Dec-42

(3)

9.32%

Funil-Itapebi, C2

198.10

230

Jul-90

Dec-42

(3)

9.32%

Fortaleza-Cauipe, C1

58.20

230

Nov-73

Dec-42

(3)

9.32%

Fortaleza-Delmiro Gouveia, C1

7.10

230

Jun-89

Dec-42

(3)

9.32%

Fortaleza-Delmiro Gouveia, C2

7.10

230

Jun-89

Dec-42

(3)

9.32%

Fortaleza-Fortaleza II, C1

0.30

230

Feb-00

Dec-42

(3)

9.32%

Fortaleza-Fortaleza II, C2

0.30

230

Feb-00

Dec-42

(3)

9.32%

Fortaleza-Fortaleza II, C3

0.30

230

Oct-05

Dec-42

(3)

9.32%

Fortaleza II-Cauipe, C1

58.00

230

Nov-03

Dec-42

(3)

9.32%

Fortaleza II-Cauipe, C2

58.00

230

Nov-03

Dec-42

(3)

9.32%

Fortaleza II-Pici, C1

27.50

230

May-09

Dec-42

(3)

9.32%

Fortaleza II-Pici, C2

27.50

230

May-09

Dec-42

(3)

9.32%

Goianinha-Santa Rita II, C1

59.00

230

Oct-77

Dec-42

(3)

9.32%

Santa Rita II-Mussuré, C1

17.00

230

Oct-77

Dec-42

(3)

9.32%

Goianinha-Mussure, C2

50.60

230

Oct-77

Dec-42

(3)

9.32%

Gov.Mangabeira-Sapeaçu, C1

23.50

230

Dec-68

Dec-42

(3)

9.32%

Gov.Mangabeira-Sapeaçu, C2

22.50

230

Feb-84

Dec-42

(3)

9.32%

Gov.Mangabeira-Sapeaçu, C3

22.60

230

Feb-84

Dec-42

(3)

9.32%

Icó-Banabuiú, C1

124.70

230

Dec-77

Dec-42

(3)

9.32%

Itapebi-Eunápolis, C1

47.00

230

Jul-90

Dec-42

(3)

9.32%

Itapebi-Eunápolis, C2

47.00

230

Jul-90

Dec-42

(3)

9.32%

Irecê-Brotas de Macaúba, C1

135.40

230

Sep-81

Dec-42

(3)

9.32%

Brotas de Macaúba-B.J Lapa, C1

204.60

230

Sep-81

Dec-42

(3)

9.32%

Itabaianinha-Itabaiana, C1

76.80

230

Aug-53

Dec-42

(3)

9.32%

Itabaiana-Jardim, C1

44.00

230

Aug-79

Dec-42

(3)

9.32%

Itabaiana-Jardim, C2

44.00

230

Aug-79

Dec-42

(3)

9.32%

Jacaracanga-Alunordeste, C1

1.80

230

May-83

Dec-42

(3)

9.32%

Jacaracanga-Dow, C1

7.90

230

Jul-77

Dec-42

(3)

9.32%

Jacaracanga-Dow, C2

7.80

230

Mar-77

Dec-42

(3)

9.32%

Jardim-Fafen, C1

12.50

230

Aug-81

Dec-42

(3)

9.32%

Jardim-Cia.Vale.Rio Doce, C1

0.80

230

Feb-07

Dec-42

(3)

9.32%

Jaguarari-Sr. do Bonfim, C1

80.70

230

Jan-80

Dec-42

(3)

9.32%

Juazeiro -Jaguarari, C1

88.00

230

Jan-80

Dec-42

(3)

9.32%

Juazeiro II-Sr.do Bonfim II, C2

148.60

230

Apr-81

Dec-42

(3)

9.32%

Libra-Libra, C1

1.50

230

Dec-91

Dec-42

(3)

9.32%

Milagres-Banabuiu, C1

225.90

230

Feb-65

Dec-42

(3)

9.32%

Milagres-Ico, C1

103.40

230

Dec-77

Dec-42

(3)

9.32%

Milagres-Banabuiu, C3

225.10

230

Dec-77

Dec-42

(3)

9.32%

Milagres-Coremas, C1

119.40

230

Nov-86

Dec-42

(3)

9.32%

Mirueira-Pau Ferro, C1

23.10

230

Oct-99

Dec-42

(3)

9.32%

Mirueira-Goianinha, C1

50.10

230

Dec-89

Dec-42

(3)

9.32%

Messias-Maceió, C1

25.90

230

Nov-96

Dec-42

(3)

9.32%

Messias-Maceió, C2

25.90

230

Nov-96

Dec-42

(3)

9.32%

Messias-Rio Largo, C1

11.90

230

Aug-86

Dec-42

(3)

9.32%

Messias-Rio Largo, C2

11.60

230

Oct-76

Dec-42

(3)

9.32%

Messias-Rio Largo, C3

11.60

230

Apr-77

Dec-42

(3)

9.32%

Mossoró-Açu, C1

71.30

230

Jul-87

Dec-42

(3)

9.32%

Natal III - Extremoz II, C1

17.00

230

Feb-14

Dec-42

(3)

9.32%

Olindina-Olindina, C1

0.20

230

May-80

Dec-42

(3)

9.32%

Olindina-Olindina, C2

0.20

230

May-80

Dec-42

(3)

9.32%

Paulo Afonso-Angelim, C1

221.30

230

Jan-53

Dec-42

(3)

9.32%

Paulo Afonso-Garanhuns II, C1

209.30

230

Jan-67

Dec-42

(3)

9.32%

Paulo Afonso-Garanhuns II, C2

209.30

230

Jan-61

Dec-42

(3)

9.32%

Paulo Afonso-Garanhuns II, C3

214.10

230

Dec-73

Dec-42

(3)

9.32%

Garanhuns II-Angelim, C1

12.30

230

Jan-61

Dec-42

(3)

9.32%

Garanhuns II-Angelim, C2

11.60

230

Dec-73

Dec-42

(3)

9.32%

Floresta II-Bom Nome,230 Kv,C1

92.20

230

Dec-74

Dec-42

(3)

9.32%

P.Afonso-Tacaratu, 230 Kv, C1

47.40

230

Oct-61

Dec-42

(3)

9.32%

Tacaratu-Bom Nome, 230 Kv, C1

137.10

230

Oct-61

Dec-42

(3)

9.32%

Paulo Afonso-Bom Nome, C3

170.80

230

Nov-78

Dec-42

(3)

9.32%

Paulo Afonso-C. Dantas, C1

134.20

230

Mar-68

Dec-42

(3)

9.32%

Paulo Afonso-C. Dantas, C2

133.80

230

Jun-72

Dec-42

(3)

9.32%

Paulo Afonso – Floresta II, C1

79.00

230

Dec-74

Dec-42

(3)

9.32%

Paulo Afonso-Itabaiana, C2

162.50

230

Apr-87

Dec-42

(3)

9.32%

Paulo Afonso-Itabaiana, C3

162.50

230

Sep-85

Dec-42

(3)

9.32%

Paulo Afonso IV-P.Afonso, C1

1.10

230

Oct-79

Dec-42

(3)

9.32%

Paulo Afonso IV-P.Afonso, C2

1.40

230

Feb-81

Dec-42

(3)

9.32%

Pau Ferro-Coteminas, C1

123.90

230

Oct-99

Dec-42

(3)

9.32%

Pau Ferro-Campina Grande II, C2

125.90

230

Oct-99

Dec-42

(3)

9.32%

Paraiso-Natal II, C1

96.20

230

May-79

Dec-42

(3)

9.32%

Paraiso-Natal II, C2

97.20

230

Apr-79

Dec-42

(3)

9.32%

Ibiapina II-Piripiri, C1

86.00

230

Aug-73

Dec-42

(3)

9.32%

Ibiapina I-Sobral, C1

103.00

230

Aug-73

Dec-42

(3)

9.32%

Pituaçu-Narandiba, C1

3.60

230

Nov-83

Dec-42

(3)

9.32%

Pituaçu-Narandiba, C2

3.60

230

Nov-83

Dec-42

(3)

9.32%

Pituaçu-Pituaçu, C1

2.00

230

Jan-77

Dec-42

(3)

9.32%

Recife II-Joairam, C1

7.40

230

Jan-67

Dec-42

(3)

9.32%

Recife II-Joairam, C2

7.40

230

Jan-67

Dec-42

(3)

9.32%

Recife II-Joairam, C3

7.40

230

Jan-61

Dec-42

(3)

9.32%

Joairam-Bongi, C1

6.30

230

Jan-53

Dec-42

(3)

9.32%

Joairam-Bongi, C2

6.40

230

Jan-67

Dec-42

(3)

9.32%

Joairam-Bongi, C3

6.40

230

Jan-61

Dec-42

(3)

9.32%

Recife II-Goianinha, C1

71.40

230

Feb-72

Dec-42

(3)

9.32%

Recife II-Goianinha, C2

71.50

230

Feb-72

Dec-42

(3)

9.32%

Recife II-Mirueira, C1

31.00

230

Jun-80

Dec-42

(3)

9.32%

Recife II-Mirueira, C2

31.50

230

Jun-80

Dec-42

(3)

9.32%

Recife II-Mirueira, C3

31.50

230

Jun-86

Dec-42

(3)

9.32%

Recife II-Pau Ferro, C1

33.20

230

Sep-04

Dec-42

(3)

9.32%

Recife II-Pau Ferro, C2

33.20

230

Sep-04

Dec-42

(3)

9.32%

Recife II-Pirapama II, C1

27.60

230

Jun-80

Dec-42

(3)

9.32%

Recife II-Pirapama II, C2

27.60

230

Jun-80

Dec-42

(3)

9.32%

Ribeirão-Recife II, C1

56.60

230

Sep-94

Dec-42

(3)

9.32%

Rio Largo-Braskem, C1

23.20

230

Jun-76

Dec-42

(3)

9.32%

Quixere-MossoróII,C1

50.20

230

Apr-81

Dec-42

(3)

9.32%

Russas II – Quixere, C1

25.40

230

Apr-81

Dec-42

(3)

9.32%

Sobral III-Sobral II, C1

13.80

230

May-09

Dec-42

(3)

9.32%

Sobral III-Sobral II, C2

13.80

230

May-09

Dec-42

(3)

9.32%

Sobral II – Cccp, 230 Kv, C1

2.90

230

Jun-01

Dec-42

(3)

9.32%

S.João Piauí-Picos, C1

167.80

230

Jul-85

Dec-42

(3)

9.32%

S.João Piaui-Eliseu Martins, C1

172.90

230

Feb-98

Dec-42

(3)

9.32%

C. Formoso-Irecê, C1

158.20

230

Sep-81

Dec-42

(3)

9.32%

Sr.do Bonfim-C. Formoso, C1

64.70

230

Sep-81

Dec-42

(3)

9.32%

Sapeaçu-Funil, C1

195.70

230

Dec-68

Dec-42

(3)

9.32%

Sapeaçu- S.Ant.Jesus, C2

32.00

230

Feb-84

Dec-42

(3)

9.32%

Sapeaçu- S.Ant.Jesus, C3

32.00

230

Feb-84

Dec-42

(3)

9.32%

S.Ant.Jesus-Funil, C2

162.60

230

Feb-84

Dec-42

(3)

9.32%

S.Ant.Jesus-Funil, C3

162.10

230

Feb-84

Dec-42

(3)

9.32%

Tacaimbo-C.Grande II, C1

124.70

230

Jun-85

Dec-42

(3)

9.32%

Tacaimbo-C.Grande II, C2

124.70

230

Jun-85

Dec-42

(3)

9.32%

Teresina I-Teresina II, C1

25.30

230

Sep-02

Dec-42

(3)

9.32%

Teresina I-Teresina II, C2

25.30

230

Sep-02

Dec-42

(3)

9.32%

Teresina-Piripiri, C1

154.70

230

Nov-71

Dec-42

(3)

9.32%

Plant Apol.Sales- P.Afonso, C1

5.80

230

Oct-77

Dec-42

(3)

9.32%

Plant Apol.Sales- P.Afonso, C2

5.70

230

Mar-77

Dec-42

(3)

9.32%

Plant B.Esperança-B.Esperança, C1

2.80

230

Dec-80

Dec-42

(3)

9.32%

Sobradinho-Juazeiro II, C1

42.50

230

Jan-80

Dec-42

(3)

9.32%

Sobradinho-Juazeiro II, C2

42.50

230

Apr-81

Dec-42

(3)

9.32%

Plant II-Paulo Afonso, C1

0.70

230

Oct-61

Dec-42

(3)

9.32%

Plant II-Paulo Afonso, C3

0.70

230

May-67

Dec-42

(3)

9.32%

Plant II-Paulo Afonso, C4

0.70

230

May-67

Dec-42

(3)

9.32%

Plant II-Paulo Afonso, C5

0.70

230

Dec-67

Dec-42

(3)

9.32%

Plant III-Paulo Afonso, C1

0.60

230

Oct-71

Dec-42

(3)

9.32%

Plant III-Paulo Afonso, C2

0.60

230

Apr-72

Dec-42

(3)

9.32%

Plant III-Paulo Afonso, C3

0.60

230

Apr-74

Dec-42

(3)

9.32%

Plant III-Paulo Afonso, C4

0.60

230

Aug-74

Dec-42

(3)

9.32%

Plant I-Paulo Afonso, C1

0.60

230

Jan-55

Dec-42

(3)

9.32%

Plant I-Paulo Afonso, C2

0.60

230

Jan-55

Dec-42

(3)

9.32%

C.Grande II-S.Cruz II, C1

117.30

138

Apr-63

Dec-42

(3)

9.32%

C.Grande II-Pilões, C1

79.30

138

Jan-68

Dec-42

(3)

9.32%

Paraíso-Santa Cruz II, C1

8.70

138

Jan-68

Dec-42

(3)

9.32%

Pilões – Paraíso, C1

107.90

138

Jan-68

Dec-42

(3)

9.32%

C. Novos-Santana do Matos, C1

38.80

138

Dec-67

Dec-42

(3)

9.32%

Santana do Matos-Açu, C1

49.60

138

Dec-67

Dec-42

(3)

9.32%

Santa Cruz II-C.Novos II, C1

55.00

138

Oct-65

Dec-42

(3)

9.32%

Plant II-Zebu, C1

6.00

138

Dec-64

Dec-42

(3)

9.32%

Abaixadora-Mulungu, C1

6.50

69

May-75

Dec-42

(3)

9.32%

Abaixadora-Moxoto, C1

5.30

69

Oct-70

Dec-42

(3)

9.32%

Abaixadora-Zebu, C1

5.40

69

Oct-72

Dec-42

(3)

9.32%

Camacari-Camacari, C2

1.40

69

Jun-60

Dec-42

(3)

9.32%

Cotegipe-Catu, C1

48.70

69

Jun-60

Dec-42

(3)

9.32%

Cotegipe-Catu, C2

48.70

69

Jun-60

Dec-42

(3)

9.32%

Jaboatao-Recife II, C1

3.10

69

Jan-65

Dec-42

(3)

9.32%

M.Reduzido-M.Reduzido, C1

0.50

69

Apr-73

Dec-42

(3)

9.32%

Matatu-Pituacu, C1

7.50

69

Jun-60

Dec-42

(3)

9.32%

Matatu-Pituacu, C2

7.40

69

Jun-60

Dec-42

(3)

9.32%

Pirapama II-Recife II, C1

21.30

69

Jan-65

Dec-42

(3)

9.32%

Pituacu-Cotegipe, C1

22.10

69

Jun-60

Dec-42

(3)

9.32%

Pituacu-Cotegipe, C2

21.90

69

Jun-60

Dec-42

(3)

9.32%

Plant de Pedra-Jequié, C1

20.50

69

Nov-78

Dec-42

(3)

9.32%

Vila Zebu-Itaparica, C1

27.00

69

Jul-77

Dec-42

(3)

9.32%

Zebu-Moxoto, C1

7.20

69

Apr-83

Dec-42

(3)

9.32%

Zebu-Xingo, C1

56.50

69

Aug-81

Dec-42

(3)

9.32%

Furnas

Foz do Iguaçu - Ivaiporã 1

322.00

765

Aug-89

Dec-42

(4)

-

Foz do Iguaçu - Ivaiporã 2

323.00

765

Dec-86

Dec-42

(4)

-

Foz do Iguaçu - Ivaiporã 3

331.00

765

Mar-99

Dec-42

(4)

-

Itaberá - Ivaiporã 1

265.00

765

Aug-89

Dec-42

(4)

-

Itaberá - Ivaiporã 2

264.00

765

Oct-82

Dec-42

(4)

-

Itaberá - Ivaiporã 3

272.00

765

May-00

Dec-42

(4)

-

Itaberá - Tijuco Preto 1

305.00

765

Jul-89

Dec-42

(4)

-

Itaberá - Tijuco Preto 2

304.00

765

Oct-82

Dec-42

(4)

-

Itaberá - Tijuco Preto 3

312.00

765

May-01

Dec-42

(4)

-

Foz do Iguaçu - Ibiúna Bipolo 1

792.00

600

Mar-85

Dec-42

(4)

-

Foz do Iguaçu - Ibiúna Bipolo 2

820.00

600

Aug-87

Dec-42

(4)

-

Adrianópolis - Baixada Fluminense

19.00

500

May-04

Dec-42

(4)

-

Adrianópolis - Cachoeira Paulista 1

171.00

500

Feb-74

Dec-42

(4)

-

Adrianópolis – Grajaú

55.00

500

Dec-77

Dec-42

(4)

-

Adrianópolis – Resende

115.00

500

Dec-79

Dec-42

(4)

-

Adrianópolis - São José

33.00

500

Aug-91

Dec-42

(4)

-

Angra - Cachoeira Paulista

103.00

500

Jun-77

Dec-42

(4)

-

Angra - São José

133.00

500

Dec-98

Dec-42

(4)

-

Angra - Zona Oeste

97.50

500

Dec-98

Dec-42

(4)

-

Araraquara – Campinas

171.00

500

Jul-76

Dec-42

(4)

-

Araraquara - Poços de Caldas

176.00

500

Apr-76

Dec-42

(4)

-

Baixada Fluminense - Cachoeira Paulista

160.50

500

May-04

Dec-42

(4)

-

Cachoeira Paulista - Campinas

223.00

500

Sep-77

Dec-42

(4)

-

Cachoeira Paulista - Itajubá

53.00

500

Jul-02

Dec-42

(4)

-

Cachoeira Paulista - Resende

56.00

500

Dec-79

Dec-42

(4)

-

Cachoeira Paulista - Taubaté

83.00

500

Jun-83

Dec-42

(4)

-

Cachoeira Paulista - Tijuco Preto 1

181.00

500

Nov-88

Dec-42

(4)

-

Campinas - Itatiba

26.50

500

Mar-03

Dec-42

(4)

-

Grajaú - Zona Oeste

79.00

500

Dec-98

Dec-42

(4)

-

Gurupi – Miracema

255.00

500

Mar-99

Dec-42

(4)

-

Ibiúna - Itatiba

86.50

500

Mar-03

Dec-42

(4)

-

Itumbiara - São Simão

166.00

500

Jan-79

Dec-42

(4)

-

Marimbondo - Água Vermelha

172.00

500

Aug-79

Dec-42

(4)

-

Marimbondo - Araraquara 1

195.00

500

Apr-76

Dec-42

(4)

-

Marimbondo - Araraquara 2

194.00

500

Aug-76

Dec-42

(4)

-

Poços de Caldas – Itajubá

139.00

500

Jul-02

Dec-42

(4)

-

Serra da Mesa – Gurupi 1

256.00

500

Mar-99

Dec-42

(4)

-

Serra da Mesa - Samambaia 1

249.00

500

Mar-98

Dec-42

(4)

-

Serra da Mesa - Samambaia 2

248.50

500

Jan-99

Dec-42

(4)

-

Tijuco Preto - Taubaté

108.50

500

Mar-84

Dec-42

(4)

-

Adrianópolis - Itutinga 1

199.00

345

Mar-68

Dec-42

(4)

-

Adrianópolis - Itutinga 2

199.00

345

Aug-70

Dec-42

(4)

-

Adrianópolis - Jacarepaguá 1

38.00

345

Mar-68

Dec-42

(4)

-

Adrianópolis - Jacarepaguá 2

38.00

345

Aug-70

Dec-42

(4)

-

Adrianópolis - Macaé

177.00

345

Sep-02

Dec-42

(4)

-

Adrianópolis - Venda das Pedras

107.00

345

Nov-01

Dec-42

(4)

-

Bandeirantes - Samambaia 1

157.00

345

Feb-99

Dec-42

(4)

-

Bandeirantes - Samambaia 2

155.00

345

Feb-99

Dec-42

(4)

-

Barro Branco - Ouro Preto

59.00

345

Mar-05

Dec-42

(4)

-

Barro Branco - Padre Fialho

104.50

345

Mar-05

Dec-42

(4)

-

Campinas - Guarulhos

88.00

345

Feb-03

Dec-42

(4)

-

Campinas - Poços de Caldas

126.00

345

Oct-72

Dec-42

(4)

-

Campos - Macaé 1

89.00

345

Nov-01

Dec-42

(4)

-

Campos - Macaé 2

89.00

345

Sep-02

Dec-42

(4)

-

Campos – Viana

199.00

345

Dec-05

Dec-42

(4)

-

Campos – Vitória

224.00

345

Sep-78

Dec-42

(4)

-

Corumbá - Brasília Sul

254.00

345

Mar-97

Dec-42

(4)

-

Corumbá – Itumbiara

79.00

345

Mar-97

Dec-42

(4)

-

Furnas - Estreito

112.00

345

Feb-70

Dec-42

(4)

-

Furnas - Itutinga 1

198.00

345

Mar-68

Dec-42

(4)

-

Furnas - Itutinga 2

199.00

345

Dec-69

Dec-42

(4)

-

Furnas - Mascarenhas de Moraes

104.00

345

May-68

Dec-42

(4)

-

Furnas – Pimenta

66.00

345

Mar-67

Dec-42

(4)

-

Furnas - Poços de Caldas 1

131.00

345

Sep-63

Dec-42

(4)

-

Furnas - Poços de Caldas 2

131.00

345

Apr-65

Dec-42

(4)

-

Guarulhos - Ibiúna 1

75.00

345

Jun-90

Dec-42

(4)

-

Guarulhos - Ibiúna 2

75.00

345

Jul-90

Dec-42

(4)

-

Guarulhos – Nordeste

35.00

345

Mar-64

Dec-42

(4)

-

Guarulhos - Poços de Caldas 1

182.00

345

Sep-63

Dec-42

(4)

-

Guarulhos - Poços de Caldas 2

184.00

345

Nov-66

Dec-42

(4)

-

Ibiúna - Tijuco Preto 1

97.00

345

Nov-83

Dec-42

(4)

-

Ibiúna - Tijuco Preto 2

97.00

345

Jul-84

Dec-42

(4)

-

Itumbiara - Bandeirantes 1

180.00

345

Jul-73

Dec-42

(4)

-

Itumbiara - Bandeirantes 2

180.00

345

Jul-77

Dec-42

(4)

-

Itumbiara - Porto Colômbia

201.00

345

Jun-73

Dec-42

(4)

-

L.C.Barreto - Estreito 1

24.00

345

Mar-69

Dec-42

(4)

-

L.C.Barreto - Estreito 2

24.00

345

Feb-70

Dec-42

(4)

-

L.C.Barreto - Poços de Caldas 1

198.00

345

Nov-69

Dec-42

(4)

-

L.C.Barreto - Poços de Caldas 2

197.00

345

Sep-70

Dec-42

(4)

-

L.C.Barreto - Volta Grande

112.00

345

Jun-73

Dec-42

(4)

-

Macaé - Venda das Pedras

122.00

345

Nov-01

Dec-42

(4)

-

Marimbondo - Porto Colômbia

77.00

345

Oct-75

Dec-42

(4)

-

Mascarenhas de Moraes - Estreito

13.00

345

Mar-69

Dec-42

(4)

-

Mogi das Cruzes – Atibaia

64.50

345

Feb-71

Dec-42

(4)

-

Mogi das Cruzes – Nordeste

25.00

345

Mar-64

Dec-42

(4)

-

Pimenta – Barreiro

198.00

345

Mar-67

Dec-42

(4)

-

Poços de Caldas – Atibaia

142.50

345

Feb-71

Dec-42

(4)

-

Porto Colômbia - Volta Grande

45.00

345

Jun-73

Dec-42

(4)

-

Brasília Sul - Samambaia 1

13.50

345

Feb-99

Dec-42

(4)

-

Brasília Sul - Samambaia 2

14.00

345

Feb-99

Dec-42

(4)

-

Viana – Vitória

26.00

345

Dec-05

Dec-42

(4)

-

Vitória - Padre Fialho

220.50

345

Mar-05

Dec-42

(4)

-

Barro Alto – Niquelândia

87.00

230

Oct-99

Dec-42

(4)

-

Brasília Geral - Brasília Sul 1

13.00

230

Oct-72

Dec-42

(4)

-

Brasília Geral - Brasília Sul 2

13.00

230

Nov-06

Dec-42

(4)

-

Barro Alto – Águas Lindas

102.00

230

Mar-82

Dec-42

(4)

-

Brasília Sul - Águas Lindas

30.00

230

Mar-82

Dec-42

(4)

-

Brasília Sul – Pirineus

107.00

230

Sep-07

Dec-42

(4)

-

Itumbiara - Cachoeira Dourada

44.00

230

Oct-73

Dec-42

(4)

-

Itumbiara - Rio Verde 1

208.00

230

Jan-86

Dec-42

(4)

-

Itumbiara - Rio Verde 2

202.00

230

Apr-92

Dec-42

(4)

-

Pirineus – Xavantes C1

40.00

230

Nov-06

Dec-42

(4)

-

Rio Verde - Barra do Peixe 1

240.00

230

Nov-87

Dec-42

(4)

-

Rio Verde - Barra do Peixe 2

240.00

230

Feb-94

Dec-42

(4)

-

Rio Verde - Cachoeira Dourada 1

175.00

230

Dec-86

Dec-42

(4)

-

Rio Verde – Rondonópolis

257.00

230

Nov-82

Dec-42

(4)

-

Serra da Mesa - Niquelândia

105.00

230

Oct-99

Dec-42

(4)

-

Adrianópolis - Cepel C1

1.50

138

Apr-81

Dec-42

(4)

-

Adrianópolis - Cepel C2

1.50

138

Apr-81

Dec-42

(4)

-

Adrianópolis - Magé C1

48.00

138

Apr-73

Dec-42

(4)

-

Adrianópolis - Magé C2

48.00

138

Jan-73

Dec-42

(4)

-

Alcântara - Adrianópolis 1

19.50

138

Jul-76

Dec-42

(4)

-

Alcântara - Adrianópolis 2

20.00

138

Dec-98

Dec-42

(4)

-

Alcântara - Adrianópolis 3

20.00

138

Dec-98

Dec-42

(4)

-

Alcântara - Imbariê - Adrianópolis

19.50

138

May-75

Dec-42

(4)

-

Angra - Angra (Ampla)

34.00

138

Apr-71

Dec-42

(4)

-

Angra - Jacuacanga

34.00

138

Oct-77

Dec-42

(4)

-

Angra - Santa Cruz

96.00

138

Oct-77

Dec-42

(4)

-

Cachoeira Paulista - Volta Redonda 1

105.00

138

Nov-86

Dec-42

(4)

-

Cachoeira Paulista - Volta Redonda 2

105.00

138

Jun-87

Dec-42

(4)

-

Campos - Cachoeiro do Itapemirim C1

106.00

138

Feb-73

Dec-42

(4)

-

Campos - Cachoeiro do Itapemirim C2

106.00

138

Feb-73

Dec-42

(4)

-

Campos – Iriri

97.00

138

Aug-73

Dec-42

(4)

-

Campos - Rocha Leão

110.00

138

Feb-73

Dec-42

(4)

-

Couto Magalhães - Parque das Emas

80.50

138

Jan-77

Dec-42

(4)

-

Iriri - Rocha Leão

13.00

138

Aug-73

Dec-42

(4)

-

Jacarepaguá - Ari Franco

44.00

138

Oct-77

Dec-42

(4)

-

Jacarepaguá – Cosmos

36.00

138

Apr-71

Dec-42

(4)

-

Jacarepaguá - Mato Alto

20.00

138

Apr-71

Dec-42

(4)

-

Jacarepaguá – Paciência

87.50

138

Jan-77

Dec-42

(4)

-

Paciência – Palmares

174.00

138

Aug-77

Dec-42

(4)

-

Jacarepaguá – ZIN

87.00

138

Jan-77

Dec-42

(4)

-

Jacuacanga - Brisamar

108.00

138

Jan-73

Dec-42

(4)

-

Muriqui - Angra (Ampla)

108.00

138

Jan-73

Dec-42

(4)

-

Muriqui - Brisamar

20.00

138

Oct-77

Dec-42

(4)

-

Mato Alto - Palmares

13.00

138

Apr-71

Dec-42

(4)

-

Parque das Emas - Rio Claro

18.00

138

Dec-98

Dec-42

(4)

-

Rio Verde - Cachoeira Dourada 2

18.00

138

Dec-98

Dec-42

(4)

-

Rio Verde - Rio Claro

46.00

138

Jun-01

Dec-42

(4)

-

Rocha Leão - Magé 1

46.00

138

Jun-01

Dec-42

(4)

-

Rocha Leão - Magé 2

1.00

138

Jul-77

Dec-42

(4)

-

Santa Cruz - Brisamar 1

1.00

138

Jul-87

Dec-42

(4)

-

Santa Cruz - Brisamar 2

13.00

138

Sep-73

Dec-42

(4)

-

Santa Cruz - Jacarepaguá

14.00

138

Sep-73

Dec-42

(4)

-

Santa Cruz - Palmares 1

16.00

138

Sep-73

Dec-42

(4)

-

Santa Cruz - Palmares 2

5.30

138

Oct-72

Dec-42

(4)

-

Santa Cruz – ZIN

24.10

138

Dec-67

Dec-42

(4)

-

Santa Cruz - ZIN - Ari Franco

24.10

138

Dec-67

Dec-42

(4)

-

Santa Cruz - ZIN - Cosmos

4.40

138

Dec-67

Dec-42

(4)

-

Imbariê São José C1

4.40

138

Dec-67

Dec-42

(4)

-

Imbariê São José C2

14.00

138

Oct-72

Dec-42

(4)

-

São José - Magé C1

22.60

138

Oct-72

Dec-42

(4)

-

São José - Magé C2

38.70

138

Nov-72

Dec-42

(4)

-

Campos Plant - Campos SE C1

38.70

138

Nov-72

Dec-42

(4)

-

Campos Plant - Campos SE C2

4.60

138

Mar-16

Jan-51

(4)

-

Eletrodo de Terra - Foz do Iguaçu 1

4.60

138

Mar-16

Jan-51

(4)

-

Eletrodo de Terra - Foz do Iguaçu 2

16.00

25

Apr-85

Dec-42

(4)

-

Eletrodo de Terra - Ibiúna 1

15.00

25

Aug-87

Dec-42

(4)

-

Eletrodo de Terra - Ibiúna 2

67.00

25

Apr-85

Dec-42

(4)

-

Eletrosul

Areia/Bateias

220.30

525

Jun-00

Dec-42

11.61

IPCA

Areia / Segredo

57.80

525

Aug-92

Dec-42

3.05

IPCA

Areia / Gov. Bento Munhoz 1

10.70

525

Sep-80

Dec-42

1.37

IPCA

Areia / Gov. Bento Munhoz 2

10.90

525

Aug-81

Dec-42

Areia/Campos Novos

176.30

525

Sep-82

Dec-42

9.29

IPCA

Areia/Curitiba

235.82

525

Jun-00

Dec-42

12.43

IPCA

Areia/Ivaiporã

173.20

525

May-82

Dec-42

9.13

IPCA

Blumenau / /Curitiba

135.70

525

Dec-83

Dec-42

7.15

IPCA

Campos Novos / Caxias

203.30

525

Dec-01

Dec-42

10.71

IPCA

Campos Novos / Machadinho

50.30

525

Jan-02

Dec-42

2.65

IPCA

Cascavel D'Oeste /Guaíra

126.20

525

Apr-01

Dec-42

2.78

IPCA

Caxias / Gravataí

78.70

525

Dec-01

Dec-42

4.15

IPCA

Caxias / Itá

256.00

525

Feb-02

Dec-42

13.49

IPCA

Curitiba –Bateias

33.50

525

Jun-00

Dec-42

1.77

IPCA

Gravataí – Nova Santa Rita

29.03

525

Apr-06

Dec-42

1.68

IPCA

Itá – Nova Santa Rita

314.75

525

Apr-06

Dec-42

16.59

IPCA

Itá / Machadinho

70.10

525

Jan-02

Dec-42

4.17

IPCA

Itá / Salto Santiago

186.80

525

Sep-87

Dec-42

9.84

IPCA

Ivaiporã / Londrina

121.90

525

Apr-88

Dec-42

6.42

IPCA

Ivaiporã / Salto Santiago

165.55

525

May-82

Dec-42

8.72

IPCA

Ivaiporã Eletrosul / Ivaiporã Furnas 1

0.79

525

Sep-82

Dec-42

0.16

IPCA

Ivaiporã Eletrosul / Ivaiporã Furnas 2

0.76

525

Feb-92

Dec-42

Ivaiporã Eletrosul / Ivaiporã Furnas 3

0.76

525

Jun-04

Dec-42

Salto Santiago / Segredo

60.90

525

Aug-92

Dec-42

3.21

IPCA

Salto Santiago/SE Salto Santiago 1, 2 e 3

2.10

525

Aug-92

Dec-42

0.09

IPCA

Anastácio – Dourados

210.90

230

Aug-94

Dec-42

4.55

IPCA

Areia / Ponta Grossa Norte

181.60

230

Oct-76

Dec-42

3.92

IPCA

Areia / Salto Osório 1

156.27

230

Jan-77

Dec-42

6.74

IPCA

Areia / Salto Osório 2

156.16

230

Dec-76

Dec-42

Areia / São Mateus do Sul

129.00

230

Jul-90

Dec-42

2.78

IPCA

Assis / Londrina Copel

114.30

230

Mar-79

Dec-42

2.47

IPCA

Atlândida 2 / Osório 2

36.00

230

May-07

Dec-42

0.97

IPCA

Atlântida 2/Gravataí 3

100.17

230

Apr-08

Dec-42

2.16

IPCA

Biguaçu – Gaspar

110.00

230

Mar-15

Dec-42

2.28

IPCA

Biguaçu – Desterro (Continente)

56.58

230

Dec-08

Dec-42

1.22

IPCA

Biguaçu –Jorge Lacerda B

129.50

230

Oct-80

Dec-42

2.80

IPCA

Biguaçu –Palhoça

20.40

230

Oct-08

Dec-42

0.55

IPCA

Blumenau – Itajaí 1

37.55

230

Jan-02

Dec-42

1.28

IPCA

Blumenau – Itajaí 2

37.55

230

Mar-02

Dec-42

Blumenau – Joinville

67.00

230

Sep-79

Dec-42

1.45

IPCA

Blumenau – Joinville Norte

72.85

230

Apr-79

Dec-42

1.57

IPCA

Campo Mourão / Apucarana

114.50

230

Feb-76

Dec-42

2.47

IPCA

Campo Mourão /Maringá

79.90

230

Feb-76

Dec-42

1.72

IPCA

Campo Mourão /Salto Osório 1

181.20

230

Feb-76

Dec-42

7.83

IPCA

Campo Mourão /Salto Osório 2

181.30

230

May-76

Dec-42

Canoinhas /São Mateus do Sul

47.70

230

Feb-88

Dec-42

1.03

IPCA

Cascavel /Cascavel D'Oeste

9.90

230

Apr-01

Dec-42

0.26

IPCA

Caxias / Caxias 5

22.49

230

Jun-09

Dec-42

0.53

IPCA

Curitiba /Joinville Norte

96.36

230

Nov-76

Dec-42

2.08

IPCA

Curitiba /São Mateus do Sul

116.70

230

Jul-90

Dec-42

2.52

IPCA

Curitiba –Joinville

99.70

230

Jun-77

Dec-42

2.15

IPCA

Dourados –Guaíra

226.50

230

Nov-91

Dec-42

4.89

IPCA

El Dorado / Guaíra

16.90

230

Oct-82

Dec-42

0.32

IPCA

Farroupilha /Caxias 5

17.90

230

Oct-05

Dec-42

0.43

IPCA

Farroupilha /Monte Claro

30.96

230

Sep-04

Dec-42

1.34

IPCA

Farroupilha /Monte Claro2

31.00

230

Sep-04

Dec-42

Monte Claro – Passo Fundo

211.50

230

Sep-04

Dec-42

Gaspar/Palhoça

118.33

230

Jan-84

Dec-42

2.89

IPCA

Gaspar/Blumenau

15.57

230

Jan-84

Dec-42

IPCA

Gaspar/Blumenau

15.00

230

Mar-15

Dec-42

0.24

IPCA

Gravataí 3/Seccionamento LT Gravataí 2 - CIAG (2 x 3,2 km em CS)

6.40

230

Nov-07

Dec-42

0.06

IPCA

Joinville – Joinville Norte

5.27

230

Nov-76

Dec-42

0.14

IPCA

Joinville / Vega do Sul 1

44.10

230

Nov-02

Dec-42

1.50

IPCA

Joinville / Vega do Sul 2

44.10

230

Nov-02

Dec-42

Jorge Lacerda "B"/ Palhoça

120.60

230

Aug-05

Dec-42

2.60

IPCA

Jorge Lacerda / Siderópolis 1

49.40

230

Jun-79

Dec-42

2.09

IPCA

Jorge Lacerda / Siderópolis 2

47.30

230

Aug-79

Dec-42

Jorge Lacerda A / Jorge Lacerda B 2

0.80

230

Oct-07

Dec-42

0.04

IPCA

Jorge Lacerda A /Jorge Lacerda

0.80

230

Dec-79

Dec-42

 

 

Jorge Lacerda B / Jorge Lacerda C 1

0.50

230

Feb-97

Dec-42

0.02

IPCA

Jorge Lacerda B / Jorge Lacerda C 2

0.50

230

Feb-97

Dec-42

 

 

Lajeado Grande / Caxias 5

65.60

230

Oct-05

Dec-42

1.42

IPCA

Lajeado Grande / Forquilhinha

116.50

230

Sep-03

Dec-42

0.30

IPCA

Londrina – Apucarana

40.40

230

Apr-88

Dec-42

0.87

IPCA

Londrina Eletrosul / Londrina Copel

31.60

230

Apr-88

Dec-42

0.68

IPCA

Londrina(Eletrosul) / Assis

156.50

230

May-05

Dec-42

3.38

IPCA

Londrina(Eletrosul) / Maringá

95.30

230

May-05

Dec-42

2.06

IPCA

Monte Claro – Nova Prata

19.90

230

Sep-04

Dec-42

1.20

IPCA

Passo Fundo – Xanxerê 1

79.30

230

May-75

Dec-42

3.42

IPCA

Passo Fundo – Xanxerê 2

79.20

230

Nov-79

Dec-42

Passo Fundo / Nova Prata 2

188.10

230

Nov-92

Dec-42

8.33

IPCA

Passo Fundo / Passo Fundo 1

0.45

230

Mar-73

Dec-42

0.02

IPCA

Passo Fundo / Passo Fundo 2

0.45

230

May-73

Dec-42

IPCA

Salto Osório – Xanxerê

162.00

230

Oct-75

Dec-42

3.50

IPCA

Salto Osório / Pato Branco

85.90

230

Dec-79

Dec-42

1.85

IPCA

Salto Osório / Salto Osório (1 a 6)

2.28

230

Nov-75

Dec-42

0.05

IPCA

Siderópolis / Forquilhinha

27.60

230

Oct-11

Dec-42

0.30

IPCA

Xanxerê / Pato Branco

79.60

230

Dec-79

Dec-42

1.72

IPCA

Anastácio / Aquidauana 1

11.10

138

Nov-06

Dec-42

0.31

IPCA

Anastácio / Aquidauana 2

11.10

138

Nov-06

Dec-42

IPCA

Araquari/Joinville GM

19.20

138

May-12

Dec-42

0.28

IPCA

Biguaçu – Florianópolis

19.50

138

Feb-02

Dec-42

0.60

IPCA

Biguaçu/ Florianópolis 2

19.50

138

Oct-90

Dec-42

IPCA

Biguaçu/Itajaí Fazenda

58.40

138

Oct-90

Dec-42

0.98

IPCA

Biguaçu/Tijucas

27.28

138

Feb-02

Dec-42

0.51

IPCA

Blumenau / Ilhota

40.20

138

Oct-88

Dec-42

0.77

IPCA

Blumenau / Gaspar

29.00

138

Sep-89

Dec-42

IPCA

Campo Grande / Mimoso 1

108.30

138

Oct-83

Dec-42

4.61

IPCA

Campo Grande / Mimoso 3

108.30

138

Sep-83

Dec-42

IPCA

Campo Grande / Mimoso 4

108.30

138

Sep-83

Dec-42

IPCA

Dourados das Nações / Ivinhema

94.70

138

Dec-83

Dec-42

0.25

IPCA

Florianópolis / Palhoça 1

9.60

138

Nov-83

Dec-42

1.41

IPCA

Florianópolis / Palhoça 2

9.60

138

Nov-83

Dec-42

IPCA

Ilhota – Picarras

14.80

138

Apr-94

Dec-42

0.28

IPCA

Ilhota / Itajaí 1

7.89

138

Mar-02

Dec-42

0.15

IPCA

Ilhota / Itajaí 2

7.89

138

Jan-02

Dec-42

IPCA

Ilhota/Araquari Hyosung

47.65

138

Sep-11

Dec-42

0.71

IPCA

Ilhota/Gaspar

11.20

138

Oct-88

Dec-42

0.21

IPCA

Itajaí / Camboriú Morro do Boi

13.31

138

Feb-02

Dec-42

0.27

IPCA

Itajaí / Itajaí Fazenda

5.35

138

Mar-02

Dec-42

0.10

IPCA

Ivinhema / Ivinhema2

30.00

138

Mar-82

Jan-44

0.36

IPCA

Ivinhema2 / Nova Andradina

27.09

138

Mar-82

Dec-42

0.31

IPCA

Nova Andradina / Porto Primavera

33.91

138

Mar-82

Dec-42

0.68

IPCA

Joinville / Joinville Santa Catarina

10.00

138

Oct-99

Dec-42

0.21

IPCA

Joinville Santa Catarina / Picarras

49.00

138

Oct-99

Dec-42

0.95

IPCA

Joinville/Joinville GM

8.63

138

May-12

Dec-42

0.19

IPCA

Jorge Lacerda A / Imbituba

45.70

138

Oct-80

Dec-42

0.87

IPCA

Jorge Lacerda A / Palhoça

108.60

138

Oct-83

Dec-42

2.07

IPCA

Jupiá – Mimoso 1

218.70

138

Feb-92

Dec-42

4.17

IPCA

Jupiá – Mimoso 3

218.70

138

Jan-82

Dec-42

2.57

IPCA

Jupiá – Mimoso 4

218.70

138

Jan-82

Dec-42

2.57

IPCA

Palhoça/Palhoça Pinheira

21.66

138

Mar-82

Dec-42

0.35

IPCA

Palhoça Pinheira/Imbituba

52.34

138

Mar-82

Dec-42

0.96

IPCA

Tijucas/Camboríu Morro do Boi

23.13

138

Feb-02

Dec-42

0.45

IPCA

Salto Osório / Salto Santiago

56.20

69

Oct-78

Dec-42

-

IPCA

(1) These substations were added because theses amounts are from Concession 058/2001.

(2) Includes RBNIA which started operation in this cycle.

(3) These Transmission Lines are part of Concession Agreement No. 061/2001 which also includes the substations listed below. The amount of active RAP related to this agreement, adjusted on 07/17/2016, is R$ 833,863,957.06.

(4) These Transmission Lines are part of Concession Agreement No. 062/2001 which also includes the substations listed below. The amount of active RAP related to this agreement, readjusted on 06/01/2016, is R$ 983,043,089.94.

 

 

AAR Consolidation 2Q17

            

Company

Corporate AAR

            

Chesf

R$ 986.996.167,01

            

Eletronorte

R$ 950.842.814,11

           

Eletrosul

R$ 898.092.353,86

            

Furnas

R$ 1.321.425.483,16

            

 

41

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex III - 2Q17

Operating Information of the Subsidiaries

 

III.4 Substation - Enterprises renewed in terms of 12,783/13 Law

         

Eletrobras Companies

SS

Transformation Capacity (MVA)

Location (State)

Beginning of Operation

End of Concession

AAR on 06.30.17 (R$ million)

Readjustment Index

Eletronorte

Altamira

180.3

PA

Jun-98

Dec-42

5.95

9.40%

Cametá

23.6

PA

Aug-98

Dec-42

0.53

9.40%

Carajás

0.3

PA

Nov-06

Dec-42

0.95

9.40%

Castanhal (1)

-

PA

Jun-12

Dec-42

0.37

9.40%

Guamá

454.0

PA

Dec-81

Dec-42

3.27

9.40%

Marabá

1,063.8

PA

Oct-81

Dec-42

13.64

9.40%

Miramar (1)

-

PA

May-16

Dec-42

0.22

9.40%

Rurópolis

300.6

PA

Dec-98

Dec-42

5.14

9.40%

Santa Maria

600.2

PA

Sep-95

Dec-42

6.50

9.40%

Tucuruí

969.0

PA

Oct-81

Dec-42

22.96

9.40%

Transamazônica

60.3

PA

Dec-98

Dec-42

4.01

9.40%

Tucuruí-Vila

58.4

PA

Jun-99

Dec-42

9.44

9.40%

Utinga

602.0

PA

Dec-81

Dec-42

4.30

9.40%

Vila do Conde

3,817.4

PA

Dec-81

Dec-42

24.51

9.40%

Integradora

-

PA

Jul-13

Dec-42

0.47

9.40%

São Luis I

401.7

MA

Dec-82

Dec-42

4.69

9.40%

São Luis II

2,829.0

MA

Dec-82

Dec-42

28.58

9.40%

Miranda II

500.6

MA

Jun-98

Dec-42

57.70

9.40%

Peritoró

300.1

MA

Dec-82

Dec-42

37.89

9.40%

Presidente Dutra

721.0

MA

Dec-82

Dec-42

16.33

9.40%

Coelho Neto

130.0

MA

Jan-00

Dec-42

1.35

9.40%

Imperatriz

1,842.2

MA

Dec-82

Dec-42

19.13

9.40%

Porto Franco (2)

399.5

MA

Feb-94

Dec-42

5.56

9.40%

Colinas

1.5

TO

Mar-99

Dec-42

2.82

9.40%

Miracema

362.5

TO

Mar-99

Dec-42

9.11

9.40%

Barra do peixe

150.6

MT

Nov-93

Dec-42

6.21

9.40%

Couto Magalhães

15.1

MT

Oct-81

Dec-42

0.97

9.40%

Coxipó

571.2

MT

Jul-87

Dec-42

7.55

9.40%

Jauru

600.5

MT

Jun-03

Dec-42

2.29

9.40%

Nobres (1)

-

MT

Sep-96

Dec-42

0.38

9.40%

Nova Mutum

60.6

MT

Sep-96

Dec-42

1.03

9.40%

Rondonopolis

400.9

MT

Jul-83

Dec-42

6.64

9.40%

Sinop

356.0

MT

Sep-96

Dec-42

5.27

9.40%

Sorriso

60.6

MT

Sep-96

Dec-42

1.28

9.40%

Epitaciolândia

22.1

AC

Mar-08

Dec-42

Isolated System. No AAR.

0.00%

Sena Madureira

18.8

AC

Oct-08

Dec-42

Isolated System. No AAR.

0.00%

Rio Branco (2)

423.0

AC

Nov-12

Dec-42

7.25

9.40%

Ariquemes

120.3

RO

Aug-94

Dec-42

1.42

9.40%

Ji-Paraná

380.6

RO

Sep-94

Dec-42

5.85

9.40%

Porto Velho

525.6

RO

Jul-89

Dec-42

3.38

9.40%

Abunã

110.6

RO

May-02

Dec-42

2.26

9.40%

Samuel

0.3

RO

Jul-89

Dec-42

0.39

9.40%

Pimenta Bueno

110.6

RO

Jun-08

Dec-42

3.65

9.40%

Vilhena

120.6

RO

Oct-08

Dec-42

3.89

9.40%

Jaru (2)

90.2

RO

Sep-97

Dec-42

3.15

9.40%

Coaracy Nunes

40.1

AP

Nov-75

Dec-42

Isolated System. No AAR.

0.00%

Portuária

20.0

AP

Apr-96

Dec-42

Isolated System. No AAR.

0.00%

Amapá

10.1

AP

Dec-01

Dec-42

Isolated System. No AAR.

0.00%

Tartarugalzinho

40.2

AP

Jun-00

Dec-42

Isolated System. No AAR.

0.00%

Calçoene

10.1

AP

May-02

Dec-42

Isolated System. No AAR.

-

Santana

120.5

AP

Oct-75

Dec-42

Isolated System. No AAR.

-

Santa Rita

80.0

AP

Dec-07

Dec-42

Isolated System. No AAR.

-

Equatorial

80.0

AP

Aug-00

Dec-42

Isolated System. No AAR.

-

Macapá II

53.4

AP

Nov-96

Dec-42

Isolated System. No AAR.

-

Boa Vista

301.7

RR

Jul-01

Dec-42

1.00

-

Chesf

SS Elev. Usina Apolonio Sales

480.0

AL

Feb-77

Dec-42

(6)

-

SS Elev. Usina Luiz Gonzaga

1,665.0

PE

May-88

Dec-42

(6)

-

SS Elev. Usina Paulo Afonso I

202.5

BA

Jan-55

Dec-42

(6)

-

SS Elev. Usina Paulo Afonso II

495.0

BA

Jan-62

Dec-42

(6)

-

SS Elev. Usina Paulo Afonso III

960.0

BA

Jan-71

Dec-42

(6)

-

SS Elev. Usina Paulo Afonso IV

2,700.0

BA

Nov-79

Dec-42

(6)

-

SS Elev. Usina Xingó

3,330.0

SE

Nov-94

Dec-42

(6)

-

SS Elev. Usina B. Esperança

280.0

PI

Mar-70

Dec-42

(6)

-

SS Elev. Usina de Funil

43.2

BA

Jan-59

Dec-42

(6)

-

SS Elev. Usina de Pedra

27.0

BA

Nov-78

Dec-42

(6)

-

SS Pau Ferro

301.0

PE

Aug-02

Dec-42

(6)

-

SS Paraiso

200.0

RN

Feb-04

Dec-42

(6)

-

SS Bom Nome

388.0

PE

Oct-63

Dec-42

(6)

-

SS Irecê

229.0

BA

Sep-81

Dec-42

(6)

-

SS Milagres

2,120.0

CE

Jan-64

Dec-42

(6)

-

SS Mirueira

401.0

PE

Aug-78

Dec-42

(6)

-

SS Moxotó

20.0

BA

Jan-72

Dec-42

(6)

-

SS Mulungú

10.0

BA

May-75

Dec-42

(6)

-

SS Pilões II

NA*

PB

Oct-12

Dec-42

(6)

-

SS Coteminas

NA*

PB

Dec-09

Dec-42

(6)

-

SS Brotas de Macaubas

NA*

BA

Jul-12

Dec-42

(6)

-

SS Tacaratu (3)

NA*

PE

Dec-14

Dec-42

(6)

-

SS Quixerê (3)

NA*

CE

Nov-14

Dec-42

(6)

-

SS Campo Formoso

NA*

BA

Dec-15

Dec-42

(6)

-

SS Jaguarari

NA*

BA

Jan-80

Dec-42

(6)

-

SS Sapeaçu

NA*

BA

May-03

Dec-42

(6)

-

SS Sobradinho

900.0

BA

Oct-79

Dec-42

(6)

-

SS Sobral II

400.0

CE

Nov-73

Dec-42

(6)

-

SS Tacaimbó

301.0

PE

Jun-85

Dec-42

(6)

-

SS Cícero Dantas

101.0

BA

May-56

Dec-42

(6)

-

SS Açu II

378.0

RN

Nov-89

Dec-42

(6)

-

SS Angelim

310.0

PE

Jan-56

Dec-42

(6)

-

SS Angelim II

NA*

PE

Jan-80

Dec-42

(6)

-

SS Bongi

530.0

PE

May-56

Dec-42

(6)

-

SS Campina Grande II

410.0

PB

May-64

Dec-42

(6)

-

SS Itapebi

NA*

BA

Jan-03

Dec-42

(6)

-

SS Funil

550.0

BA

Jan-56

Dec-42

(6)

-

SS SSnhor Do Bonfim II

433.3

BA

May-81

Dec-42

(6)

-

SS Eunápolis

400.0

BA

Sep-98

Dec-42

(6)

-

SS Picos

173.0

PI

Jul-92

Dec-42

(6)

-

SS Modelo Reduzido

12.5

BA

Jan-67

Dec-42

(6)

-

SS Mossoró II

400.0

RN

Jan-77

Dec-42

(6)

-

SS Barreiras

401.0

BA

Jun-96

Dec-42

(6)

-

SS Sto. Antonio de Jesus

301.0

BA

Mar-97

Dec-42

(6)

-

SS Icó

200.0

CE

May-97

Dec-42

(6)

-

SS Mussuré II

401.0

PB

Mar-79

Dec-42

(6)

-

SS Paulo Afonso

NA*

AL

Mar-74

Dec-42

(6)

-

SS Penedo

302.0

AL

May-97

Dec-42

(6)

-

SS Cauípe

201.0

CE

Mar-01

Dec-42

(6)

-

SS Pici II

500.0

CE

May-05

Dec-42

(6)

-

SS Piripiri

330.0

PI

Aug-73

Dec-42

(6)

-

SS Pituaçu

402.0

BA

Mar-83

Dec-42

(6)

-

SS Santa Cruz II

100.0

RN

Mar-63

Dec-42

(6)

-

SS Banabuiú

121.0

CE

Jan-64

Dec-42

(6)

-

SS Currais Novos II

103.0

RN

Nov-75

Dec-42

(6)

-

SS Santana dos Matos II

50.0

RN

Nov-75

Dec-42

(6)

-

SS Coremas

300.0

PB

Dec-90

Dec-42

(6)

-

SS Fortaleza

405.0

CE

Jan-64

Dec-42

(6)

-

SS Joairam

451.0

PE

Jul-06

Dec-42

(6)

-

SS Juazeiro da Bahia II

402.0

BA

Apr-81

Dec-42

(6)

-

SS Matatu

380.0

BA

Jan-65

Dec-42

(6)

-

SS Natal II

401.0

RN

Jan-79

Dec-42

(6)

-

SS Itabaianinha

240.0

SE

Feb-96

Dec-42

(6)

-

SS Pirapama II

400.0

PE

Feb-72

Dec-42

(6)

-

SS Russas II

300.0

CE

Nov-82

Dec-42

(6)

-

SS Elizeu Martins

101.0

PI

Jan-06

Dec-42

(6)

-

SS Boa Esperança 230 Kv

127.0

PI

Mar-70

Dec-42

(6)

-

SS Boa Esperança 500 Kv

300.0

PI

Nov-80

Dec-42

(6)

-

SS Xingó 500 Kv

NA*

SE

Nov-94

Dec-42

(6)

-

SS Paulo Afonso IV

1,200.0

AL

Jan-79

Dec-42

(6)

-

SS Recife II

2,410.0

PE

Jan-79

Dec-42

(6)

-

SS S. João do Piaui

418.0

PI

Nov-80

Dec-42

(6)

-

SS Zebu

38.0

AL

Nov-76

Dec-42

(6)

-

SS Abaixadora

110.0

BA

Oct-67

Dec-42

(6)

-

SS Bom Jesus da Lapa

162.0

BA

Sep-81

Dec-42

(6)

-

SS Gov. Mangabeira

200.0

BA

Mar-60

Dec-42

(6)

-

SS Quixadá

NA*

CE

Jul-03

Dec-42

(6)

-

SS Jacaracanga

301.0

BA

Jan-82

Dec-42

(6)

-

SS Ribeirão

400.0

PE

Oct-94

Dec-42

(6)

-

SS Rio Largo II

301.0

AL

Dec-62

Dec-42

(6)

-

SS Messias

1,201.0

AL

Nov-94

Dec-42

(6)

-

SS Camaçari II

2,605.0

BA

Jan-79

Dec-42

(6)

-

SS Catu

300.0

BA

May-56

Dec-42

(6)

-

SS Cotegipe

302.0

BA

Jan-56

Dec-42

(6)

-

SS Teresina

590.0

PI

Apr-70

Dec-42

(6)

-

SS Fortaleza II

2,400.0

CE

May-00

Dec-42

(6)

-

SS Goianinha

300.0

PE

Jan-61

Dec-42

(6)

-

SS Teresina II

900.0

PI

May-00

Dec-42

(6)

-

SS Delmiro Gouveia

401.0

CE

Jun-89

Dec-42

(6)

-

SS Maceió

400.0

AL

Sep-02

Dec-42

(6)

-

SS Itabaiana

200.0

SE

May-57

Dec-42

(6)

-

SS Itaparica

10.0

PE

Jan-83

Dec-42

(6)

-

SS Jardim

1,601.0

SE

Aug-79

Dec-42

(6)

-

SS Sobral III

1,200.0

CE

Apr-00

Dec-42

(6)

-

SS Xingó 69 Kv

12.5

SE

Jan-87

Dec-42

(6)

-

SS Olindina

40.0

BA

Apr-80

Dec-42

(6)

-

SS Luiz Gonzaga 500kv

NA*

PE

May-88

Dec-42

(6)

-

SS Floresta II (3)

NA*

PE

Oct-14

-

(6)

-

 

 

 

 

 

 

 

Furnas (4)

Adrianópolis

3,290.0

RJ

Nov-70

Dec-42

(7)

-

Angra

974.6

RJ

Apr-71

Dec-42

(7)

-

Araraquara

-

SP

Apr-76

Dec-42

(7)

-

Bandeirantes

1,433.3

GO

Oct-72

Dec-42

(7)

-

Barro Alto

183.0

GO

Mar-82

Dec-42

(7)

-

Brasília Geral

300.0

DF

Feb-60

Dec-42

(7)

-

Brasília Sul

2,094.2

DF

Mar-73

Dec-42

(7)

-

Cachoeira Paulista

583.3

SP

Oct-76

Dec-42

(7)

-

Campinas

1,970.0

SP

Sep-72

Dec-42

(7)

-

Campos

1,283.3

RJ

Feb-73

Dec-42

(7)

-

Foz do Iguaçu

15,968.0

PR

Dec-82

Dec-42

(7)

-

Grajaú

2,800.0

RJ

Dec-79

Dec-42

(7)

-

Guarulhos

-

SP

Sep-63

Dec-42

(7)

-

Gurupi

-

TO

Mar-99

Dec-42

(7)

-

Ibiúna

12,050.4

SP

Apr-84

Dec-42

(7)

-

Imbariê

-

RJ

Oct-68

Dec-42

(7)

-

Iriri

-

RJ

Oct-09

Dec-42

(7)

-

Itabera

-

SP

Sep-82

Dec-42

(7)

-

Itutinga

-

MG

Apr-67

Dec-42

(7)

-

Ivaiporã

10,956.0

PR

Oct-82

Dec-42

(7)

-

Jacarepaguá

1,350.0

RJ

Dec-67

Dec-42

(7)

-

Macaé

-

RJ

Nov-01

Dec-42

(7)

-

Mogi das Cruzes

1,166.7

SP

Mar-64

Dec-42

(7)

-

Niquelândia

-

GO

Oct-99

Dec-42

(7)

-

Pirineus

-

GO

Nov-06

Dec-42

(7)

-

Poços de Caldas

1,846.7

MG

Sep-63

Dec-42

(7)

-

Resende

-

RJ

Apr-09

Dec-42

(7)

-

Rio Verde

333.3

GO

Dec-75

Dec-42

(7)

-

Rocha Leão

-

RJ

Dec-72

Dec-42

(7)

-

Samambaia

4,250.0

DF

Mar-98

Dec-42

(7)

-

São José

2,600.0

RJ

Aug-91

Dec-42

(7)

-

Tijuco Preto

17,014.7

SP

Sep-82

Dec-42

(7)

-

Viana

750.0

ES

Dec-05

Dec-42

(7)

-

Vitória

969.2

ES

Nov-78

Dec-42

(7)

-

Corumbá

556.0

GO

Mar-97

Dec-42

(7)

-

Funil

300.0

RJ

Dec-69

Dec-42

(7)

-

Furnas

1,399.2

MG

Sep-63

Dec-42

(7)

-

Luiz C. Barreto

1,333.3

SP

Mar-69

Dec-42

(7)

-

Marimbondo

2,393.3

MG

Aug-75

Dec-42

(7)

-

Porto Colômbia

425.0

MG

Jul-73

Dec-42

(7)

-

SS Barreiro / Cemig

350.0

MG

Jan-63

Dec-42

(7)

-

SS Ouro Preto / Cemig

533.3

MG

Feb-04

Dec-42

(7)

-

HPU Água Vermelha / AES Rio Grande

1,000.0

MG

Jan-02

Dec-42

(7)

-

HPU Cachoeira Dourada / Celg

160.0

GO

Jan-86

Dec-42

(7)

-

Margem Direita (HPU Itaipu) / Ande

7.0

Hernandarias/Paraguai

Apr-83

Dec-42

(7)

-

Eletrosul

Alegrete

83.0

RS

May-71

Dec-42

2.43

IPCA

Anastácio

150.0

MS

Aug-94

Dec-42

2.34

IPCA

Areia

672.0

PR

Aug-80

Dec-42

14.04

IPCA

Assis (5)

336.0

SP

Mar-79

Dec-42

3.73

IPCA

Atlântida 2

249.0

RS

May-07

Dec-42

3.58

IPCA

Biguaçu

300.0

SC

Apr-08

Dec-42

4.89

IPCA

Blumenau

1,962.0

SC

Apr-79

Dec-42

18.90

IPCA

Campos Novos

2,466.0

SC

Sep-82

Dec-42

21.92

IPCA

Canoinhas

375.0

SC

Feb-88

Dec-42

3.27

IPCA

Caxias

2,016.0

RS

Dec-01

Dec-42

17.54

IPCA

Caxias 5 (5)

215.0

RS

Jun-05

Dec-42

4.31

IPCA

Charqueadas

88.0

RS

Jan-72

Dec-42

3.21

IPCA

Curitiba

1,344.0

PR

Oct-80

Dec-42

15.72

IPCA

Desterro

150.0

SC

Dec-08

Dec-42

2.32

IPCA

Dourados

300.0

MS

Nov-87

Dec-42

5.06

IPCA

Farroupilha

88.0

RS

Jun-73

Dec-42

4.24

IPCA

Florianópolis

75.0

SC

Dec-74

Dec-42

2.45

IPCA

Gravataí

2,016.0

RS

Sep-82

Dec-42

16.93

IPCA

Gravataí 3

165.0

RS

Nov-07

Dec-42

3.09

IPCA

Ilhota

100.0

SC

Dec-76

Dec-42

5.10

IPCA

Itajaí

450.0

SC

Jan-02

Dec-42

5.56

IPCA

Joinville

691.0

SC

Nov-74

Dec-42

9.73

IPCA

Joinville Norte

300.0

SC

Jun-09

Dec-42

4.19

IPCA

Jorge Lacerda "A"

399.8

SC

Jun-73

Dec-42

7.06

IPCA

Londrina

1,344.0

PR

Apr-88

Dec-42

11.15

IPCA

Nova Santa Rita

2,016.0

RS

Aug-09

Dec-42

16.25

IPCA

Palhoça

384.0

SC

Jan-84

Dec-42

6.99

IPCA

Passo Fundo

168.0

RS

Nov-92

Dec-42

5.38

IPCA

Salto Osório

33.3

PR

Oct-75

Dec-42

3.61

IPCA

Salto Santiago

15.0

PR

Nov-80

Dec-42

6.21

IPCA

Santo Ângelo

1,344.0

RS

Dec-99

Dec-42

15.82

IPCA

Siderópolis

352.0

SC

Apr-75

Dec-42

4.61

IPCA

Tapera 2

166.0

RS

Mar-05

Dec-42

2.18

IPCA

Xanxerê

600.0

SC

Jun-83

Dec-42

5.30

IPCA

Line inputs, reactors, capacitor banks and other equipment in substations

-

SC, PR e RS

Diverses

Dec-42

29.54

IPCA

(1) These substations were added because theses amounts are from Concession 058/2001.

(2) Including RBNIA which started operation in this cycle.

(3) Substations transferred to Chesf by donation by accessory, according to contractual clause between ANEEL and the agents that needed to build these facilities.

(4) Total Transformation Capacity (Total MVA) = Operating Capacity + Reserve Capacity + Capacity under review.

(5) Transformers installed in third-party substations.

(6) These Substations are part of Concession Agreement No. 061/2001 which also includes the Transmission Lines listed above. The amount of active AAR related to this agreement, adjusted on 07/01/2016, is R$ 833,863,957.06.

(7) These Substations are part of Concession Agreement No. 062/2001 which also includes the Transmission Lines listed above. The amount of active AAR related to this agreement, readjusted on 06/01/2016, is R$ 983,043,089.94.

NA* - Not applicable because the SS has no transformation capacity.

 

 

42

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex III - 2Q17

Operating Information of the Subsidiaries

 

III.4.2 Substation – Enterprises not renewed under 12,783/13 law terms

Eletrobras Companies

SS

Transformation Capacity (MVA)

Location (State)

Beginning of Operation

End of Concession

AAR em 06.30.17 (R$ Million)(1)

Readjustment Index

Eletronorte

Ribeiro Gonçalves (1)

650.0

MA

Dec-11

Jan-39

11.72

9.32%

Balsas (1)

200.0

MA

Dec-11

Jan-39

3.24

9.32%

São Luis III

300.3

MA

May-10

Mar-38

4.42

9.32%

Miranda II (ATR1)

450.0

MA

Nov-10

Jan-39

10.14

9.32%

Lucas do Rio Verde

75.0

MT

Apr-13

Jun-41

2.55

-3.75%

Nobres

200.0

MT

Sep-13

Dec-41

2.05

9.32%

Tucuruí

300.0

PA

Dec-14

Dec-41

2.24

9.32%

Lechuga

450.0

AM

Mar-15

May-42

7.38

9.32%

Coletora Porto Velho

5438.4

RO

Mar-13

Feb-39

69.32

9.32%

Miramar

450.0

PA

Apr-16

Apr-46

4.19

9.32%

Araraquara (inverter)

3505.2

SP

Mar-13

Feb-39

112.65

9.32%

Porto Velho (rectifier)

5438.4

RO

Mar-13

Feb-39

118.90

9.32%

Rio Branco (EX RBTE)

0.0

AC

Oct-11

Nov-39

5.15

9.32%

Chesf

SS Elev. Usina de Curemas

5.0

PB

Jan-68

Nov-24

-

-

SS Elev. Usina Term. Camaçari

400.0

BA

Sep-78

Aug-27

-

-

SS Elev. Usina de Sobradinho

1200.0

BA

Oct-79

Feb-22

-

-

SS Tauá II

202.0

CE

Dec-07

Mar-35

(5)

(5)

SS Ibicoara

410.0

BA

Jan-11

Jun-37

(5)

(5)

SS Santa Rita II

450.0

PB

Jul-12

Aug-39

(5)

(5)

SS Suape III

300.0

PE

Jul-12

Jan-39

(5)

(5)

SS Natal III

300.0

RN

Aug-12

Aug-39

(5)

(5)

SS Zebu II

200.0

AL

Jul-12

Aug-39

(5)

(5)

SS Brumado

NA

BA

Aug-10

Jun-37

(5)

(5)

SS Camaçari IV

2400.0

BA

Nov-12

Jul-40

9.72

1.09%

SS Suape II

1200.0

PE

Dec-12

Jan-39

(5)

(5)

SS Arapiraca III

200.0

AL

Jun-13

Oct-40

7.24

1.09%

SS Extremoz II

150.0

RN

Feb-14

Nov-40

(5)

(5)

SS João Câmara

360.0

RN

Feb-14

Nov-40

(5)

(5)

SS Acaraú

200.0

CE

Apr-14

Nov-40

(5)

(5)

SS Igaporã

450.0

BA

Jun-14

Nov-40

(5)

(5)

SS Aquiraz II (2)

NA

CE

Dec-13

-

(5)

(5)

SS Pecém II (2)

NA

CE

Oct-13

-

(5)

(5)

SS Ceará Mirim II (2)

NA

RN

Sep-14

-

(5)

(5)

SS Bom Jesus da Lapa II

NA

BA

Dec-15

Nov-40

(5)

(5)

SS Igaporã III

1500.0

BA

Dec-15

Jun-42

(5)

(5)

SS Pindaí II

300.0

BA

Dec-15

Jun-42

(5)

(5)

SS Campina Grande III (2)

NA

PB

Dec-15

Oct-41

(5)

(5)

SS Garanhuns II (2)

NA

PE

Dec-15

Dec-41

(5)

(5)

SS Lagoa Nova II

450.0

RN

Dec-15

Oct-41

3.45

1.09%

SS Mirueira II

300.0

PE

Apr-16

Jun-42

(5)

(5)

SS Polo

100.0

BA

Apr-16

Oct-40

1.31

1.09%

SS Ibiapina II (3)

200.0

PI

Sep-16

Aug-41

3.56

1.09%

SS Touros

150.0

RN

May-17

Jun-42

2.50

1.09%

SS Tabocas do Brejo Velho (4)

NA*

BA

Jun-17

-

-

-

Furnas (9)

Zona Oeste

1200.0

RJ

Dec-14

May-42

-

IPCA

Batalha

90.0

MG

Aug-06

Aug-41

(7)

-

Campos

186.0

RJ

Dec-68

Jul-27

(7)

-

Itumbiara

5075.0

MG

Mar-73

Feb-20

(7)

-

Manso

312.5

MT

Nov-00

Feb-35

(7)

-

Mascarenhas de Moraes

1650.7

MG

Dec-56

Oct-23

(7)

-

Santa Cruz (8)

1544.0

RJ

Jun-67

Jul-15

(7)

-

São Gonçalo

42.5

RJ

Jul-77

(6)

(7)

-

Serra da Mesa

1576.4

GO

Mar-98

Nov-39

(7)

-

Simplício

497.5

RJ

Aug-06

Aug-41

(7)

-

Eletrosul

Foz do Chapecó

150.0

RS

Dec-12

Jun-41

3.9

IPCA

Missões

150.0

RS

Nov-10

Jan-39

5.2

IPCA

Biguaçu

2016.0

SC

Apr-08

Mar-35

35.7

IPCA

Concession 010/2005 - Lines/reactor inputs/capacitor bank / other substation equipment

-

SC

Diverses

Mar-35

10.4

IPCA

Caxias 6

330.0

RS

Aug-12

Oct-40

4.1

IPCA

Ijuí 2

166.0

RS

Apr-13

Oct-40

3.4

IPCA

Lajeado Grande

75.0

RS

Nov-12

Oct-40

1.7

IPCA

Lajeado Grande - Expansion

75.0

RS

Sep-16

Oct-40

1.7

IPCA

Nova Petrópolis 2

83.00

RS

Nov-12

Oct-40

2.4

IPCA

Concession 012/2010 - Line inputs at substations

0.0

RS

Jul-13

Oct-40

1.0

IPCA

Frequency Converter Uruguaiana

109.7

RS

Sep-94

Jul-21

9.6

IPCA

Ivinhema 2 (10)

300.0

MS

Jan-16

Jan-44

3.2

IPCA

Biguaçu – expansion

300.0

SC

Oct-12

Dec-42

4.1

IPCA

Itajaí – expansion

150.0

RS

Dec-13

Dec-42

1.0

IPCA

Joinville Norte - expansion

150.0

SC

Sep-13

Dec-42

4.5

IPCA

Joinville Norte - 2nd expansion

150.0

SC

Aug-16

Dec-42

2.2

IPCA

Nova Santa Rita – expansion

672.0

RS

Dec-13

Dec-42

6.8

IPCA

Tapera 2 - expansion

83.0

RS

Nov-12

Dec-42

1.9

IPCA

Desterro - Expansion

150.0

SC

Jul-16

Dec-42

2.2

IPCA

Concession 057/2001 - Line / reactor inputs / capacitor bank / other substation equipment

0.0

SC, PR e RS

Diverses

Dec-42

11.7

IPCA

Concession 005/2006 - Line / reactor inputs / capacitor bank / other substation equipment

0.0

RS e SC

Diverses

Apr-36

8.2

IPCA

Concession 004/2004 - Line / reactor inputs / capacitor bank / other substation equipment

0.0

PR

Diverses

Feb-34

20.8

IPCA

Concession 004/2008 - Line / reactor inputs / capacitor bank / other substation equipment

-

RS

Jan-10

Mar-38

0.7

IPCA

(1) Including RBNIA which started operation in this cycle.

(2) Substations belonging to SPEs in which Chesf has its own equipment installed with at least one line input.

(3) Although energized, the reported revenue of SS Ibiapina is still foreseen since it has not yet entered commercial operation.

(4) Transfer by donation by Enel Green Power. AAR not defined yet, SS in transfer process.

(5) The AAR of these SSs is informed jointly with that of the TLs, according to concession contract.

(6) Extension denied

(7) These facilities are not part of the Furnas transmission contracts.

(8) Affected, but not yet extended.

(9) Total Transformation Capacity (Total MVA) = Operating Capacity + Reserve Capacity + Capacity under review.

(10) Transformers installed in third-party substations.

 

 

43

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex III - 2Q17

Operating Information of the Subsidiaries

IV.1 Distribution Data

       

Company

Extension of Distribution Lines (Km)

Number of Customers

Number of Municipalities Assisted

Substations

ED Acre

20,340

258,122

22

13

ED Alagoas

42,945

1,142,602

102

40

ED Amazonas Energia

31,309

961,083

62

27

ED Piauí

92,204

1,247,040

224

85

ED Rondônia

58,047

622,026

52

60

ED Roraima

3,681

114,170

1

3

 

44

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex III - 2Q17

Operating Information of the Subsidiaries

 

Companies information

  
   

IV.2 Energy Sold – MWh

  

Companies

2Q17

ED Acre

250,452

ED Alagoas

927,662

ED Amazonas Energia

1,440,139

ED Piauí

834,528

ED Rondônia

745,598

ED Roraima

183,775

Total

4,381,775

 

45

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex III - 2Q17

Operating Information of the Subsidiaries

 

IV.2.1 Energy Sold by Consumer Class

Distribution to

1Q17

2Q17

R$ million

MWh

R$ million

MWh

Captive Market

        

Residential

1,113.83

1,718,338

1,012.7

1,755,300.1

Industrial

238.97

487,382

207.8

457,515

Commercial, services and others activities

533.75

851,917

480.7

856,787

Rural

81.70

223,331

66.8

174,064

Public Utilities

171.39

326,185

175.0

359,948

Public Ilumination

75.03

202,736

87.9

260,892

Public service

56.38

140,080

51.6

137,103

Own Consumption

2.44

6,596

2.9

7,867

Others

- 4.63

3,203

- 1.7

2,259.880

Captive Total

2,268.86

3,959,768

2,084

4,011,737

Free Costumer

 

 

 

 

Residential

2.72

26,609

2.9

28,278.8

Industrial

2.15

206,136

2.9

229,088.1

Commercial, services and others activities

3.52

64,794

3.4

79,425.9

Rural

-

-

-

-

Public Utilities

-

-

-

-

Public Ilumination

-

-

-

-

Public service

-

32,947

0

33625.278

Own Consumption

-

-

-

-

Others

-

-

-

-

Free Costumer Total

8.39

330,485

9.2

370,418.1

 

 

 

 

 

Total Energy Sold

2,277.25

4,290,253.4

2,092.9

4,382,155.1

 

 

46

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex III - 2Q17

Operating Information of the Subsidiaries

IV.3 Energy purchased for resale

Company

Buyer

1Q17

2Q17

R$ Million

MWh

R$ Million

MWh

ED Acre

Eletrobras System

108.75

235,092.61

112.30

241,217.80

Others

65.25

50,775.00

65.75

53,883.89

ED Alagoas

Eletrobras System

40.90

243,220

38.00

253,891

Others

166.40

972,877

265.80

1,015,563

ED Amazonas Energia

Eletrobras System

-

-

108.60

1,385,776.32

Others

457.80

1,820,504.00

84.90

1,263,475.58

ED Piauí

Eletrobras System

35.09

342,809

35.87

350,513

Others

228.55

1,188,787

233.68

1,215,501

ED Rondônia

Eletrobras System

45.16

257,086

74.76

261,110

Others

167.16

951,683

276.75

966,577

ED Roraima

Eletrobras System

60.90

251,345

60.68

250,503

Others

50.97

26,847

35.29

29,894

 

47

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex III - 2Q17

Operating Information of the Subsidiaries

 

 

IV.4 Network Expansion – number of new connections

Company

1Q17

2Q17

ED Acre

2,395

2,626

ED Alagoas

10,553

14,941

ED Amazonas Energia

8,965

7,141

ED Piaui

16,063

12,498

ED Rondonia

5,756

8,387

ED Roraima

2,584

-

 

48

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex III - 2Q17

Operating Information of the Subsidiaries

 

IV.5 Fuel used to produce electric energy

Company

Type (Unit)

1Q17

2Q17

Amount

R$ Million

Amount

R$ Million

ED Acre

Diesel Oil (L)

17,172,986.0

-

15,304,684.0

-

Gas (m3)

 

 

 

 

ED Alagoas

Diesel Oil (L)

-

-

-

-

Gas (m3)

 

 

 

 

ED Amazonas Energia

Diesel Oil (L)

107,865,885.0

340.5

108,679,503.0

350.9

Gas (m3)

219,557,768.0

336.7

223,609,494.0

343.5

ED Piauí

Diesel Oil (L)

-

-

-

-

Gas (m3)

 

 

 

 

ED Rondônia

Diesel Oil (L)

-

-

-

-

Gas (m3)

 

 

 

 

ED Roraima

Diesel Oil (L)

7,543,264.0

24.9

6,940,148.0

24.2

Gas (m3)

 

 

 

 

 

 

49

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex III - 2Q17

Operating Information of the Subsidiaries

 

IV.6 Quality Indicators and Operational Performance

Company

DEC/ Stoppage Duration –
hours

FEC Stoppage Frequency

TMA – Average Time of Assistence –
minutes

Losses (%)

Technical

Commercial

ED Acre

27.7

18.8

451.7

9.9

13.5

ED Alagoas

11.3

7.5

337.4

10.3

15.0

ED Amazonas

20.6

14.1

271.6

7.8

36.2

ED Piauí

12.2

8.0

475.4

12.2

17.2

ED Rondônia

15.4

9.7

304.2

11.2

18.3

ED Roraima

5.9

12.4

101.9

7.0

6.5

 

 

50

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex III - 2Q17

Operating Information of the Subsidiaries

 

IV.7 Default - R$ Million

              

Class

ED
Acre

ED
Alagoas

ED Amazonas Energia

ED
Piauí

ED
Rondônia

ED Roraima

Total

Residential

29.82

97.43

201.30

113.63

64.59

23.08

529.85

Industrial

2.87

17.96

75.96

12.32

14.68

1.21

125.00

Commercial, services and others activities

8.94

32.73

79.89

44.30

20.85

5.60

192.30

Rural

4.44

12.56

6.72

6.71

13.46

1.84

45.73

Public Utilities

20.18

23.91

106.73

13.77

8.64

10.62

183.84

Public Ilumination

9.69

18.20

5.46

6.37

5.13

0.42

45.27

Public service

3.32

9.40

45.16

7.39

16.97

13.39

95.62

Own Consumption

-

-

1.03

-

-

-

1.03

Others

1.41

0.93

-

0.40

9.84

-

12.58

Total

80.67

213.12

522.26

204.87

154.17

56.16

1,231.24

 

 

51

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex III - 2Q17

Operating Information of the Subsidiaries

 

 

IX. Employees - Effective Headcount

       

IX.1 By Department

Eletrobras companies

Administrative

Operational

Total

Cepel

85

309

394

Eletronorte

989

2,045

3,034

Chesf

1,495

3,054

4,549

Furnas

1,150

2,616

3,766

Eletronuclear

511

1,443

1,954

Eletrosul

531

815

1,346

CGTEE

103

481

584

Amazonas GT

152

313

465

Itaipu Binacional

988

379

1,367

ED Acre

90

171

261

ED Alagoas

320

837

1,157

ED Amazonas Energia

457

1,251

1,708

ED Piauí

229

1,817

2,046

ED Rondônia

170

521

691

ED Roraima

151

249

400

Eletropar

4

-

4

Total

7,425

16,301

23,726

       
       

IX.2 Complementary Work-force

    

Eletrobras companies

1T17

2Q17

  

Cepel

-

-

 

Eletronorte

-

-

 

Chesf

-

-

 

Furnas

1,067

1,063

 

Eletronuclear

-

-

 

Eletrosul

-

-

 

CGTEE

-

-

 

Amazonas GT

15

-

 

Itaipu Binacional

-

-

 

ED Acre

402

402

 

ED Alagoas

929

201

 

ED Amazonas Energia

-

2,004

 

ED Piauí

1,108

1,117

 

ED Rondônia

1,274

1,230

 

ED Roraima

219

219

 

Eletropar

-

-

 

Total

5,014

6,236

  

 

 

 

 

52

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex III - 2Q17

Operating Information of the Subsidiaries

VI. Investments Eletrobras Companies

    
       

VI.1 Total Investment – R$ Million

      

Generation

1Q17

2Q17

Budget 2017

Eletrobras

-

-

 

Eletronorte

0.04

0.35

10.05

Chesf

49.97

42.32

114.56

Furnas

2.29

5.84

46.49

Eletronuclear

72.77

94.66

1,496.89

Eletrosul

-

0.08

0.79

CGTEE

-

-

1.79

Amazonas GT

14.87

23.91

93.09

Itaipu Binacional

-

-

-

ED Amazonas Energia

-

-

4.30

Furnas Subsidiaries (1)

0.35

0.12

-

Eletrosul Subsidiaries (2)

-

0.79

-

       
       

Generation - Maintenance

1Q17

2Q17

Budget 2017

Eletrobras

-

-

-

Eletronorte

1.81

0.43

26.17

Chesf

4.91

7.94

43.41

Furnas

5.72

3.34

40.74

Eletronuclear

15.31

36.01

293.93

Eletrosul

0.71

0.04

11.50

CGTEE

1.52

0.18

62.57

Amazonas GT

0.78

0.42

10.84

Itaipu Binacional

-

-

-

ED Amazonas Energia

0.06

1.47

6.70

Furnas Subsidiaries (1)

-

-

-

Eletrosul Subsidiaries (2)

-

-

-

       
       

Generation – Partnership Investments

1Q17

2Q17

Budget 2017

Eletrobras

92.25

22.20

200.00

Eletronorte

142.48

66.32

709.28

Chesf

125.45

53.49

443.09

Furnas

51.13

117.97

381.51

Eletronuclear

27.74

28.30

67.78

Eletrosul

-

-

-

Furnas Subsidiaries (1)

-

-

-

       
       

Transmission

1Q17

2Q17

Budget 2017

Eletrobras

-

-

6.00

Eletronorte

9.83

16.80

584.13

Chesf

81.30

92.11

433.41

Furnas

17.01

27.79

179.55

Eletrosul

14.20

20.64

86.97

Amazonas GT

-

0.33

34.76

ED Amazonas Energia

-

-

-

Furnas Subsidiaries

9.34

12.25

-

Eletrosul Subsidiaries

1.49

15.48

-

Other Companies (3)

-

-

-

       
       

Transmission - Maintenance

1Q17

2Q17

Budget 2017

Eletrobras

-

-

-

Eletronorte

5.01

2.54

73.29

Chesf

22.27

36.47

118.06

Furnas

24.62

45.89

150.57

Eletrosul

1.45

0.80

3.45

Amazonas GT

-

-

2.31

ED Amazonas Energia

-

-

-

Furnas Subsidiaries

-

-

-

Eletrosul Subsidiaries

-

-

-

Other Companies (3)

-

-

-

       
       

Transmission – Partnership Investments

1Q17

2Q17

Budget 2017

Eletrobras

-

-

-

Eletronorte

42.00

85.65

276.14

Chesf

-

-

10.87

Furnas

154.36

105.32

294.89

Eletrosul

0.12

0.19

54.50

Amazonas GT

-

-

-

ED Amazonas Energia

-

-

-

Other Companies (3)

-

-

-

       
       

Distribution - Expansion

1Q17

2Q17

Budget 2017

ED Acre

3.99

2.41

59.68

ED Alagoas

15.14

23.72

176.83

ED Amazonas Energia

10.82

21.55

380.36

ED Piauí

9.70

24.43

205.73

ED Rondônia

10.38

42.41

153.54

ED Roraima

2.20

1.71

38.01

CELG D

41.14

-

-

       
       

Distribution - Maintenance

1Q17

2Q17

Budget 2017

ED Acre

1.65

4.27

14.02

ED Alagoas

9.40

10.44

96.13

ED Amazonas Energia

13.02

10.15

133.25

ED Piauí

8.46

13.48

66.47

ED Rondônia

12.46

0.54

82.11

ED Roraima

0.24

1.46

5.97

CELG D

14.77

-

-

       

Others (4)

1Q17

2Q17

Budget 2017

Eletrobras

0.18

-

23.98

Eletronorte

2.23

2.23

44.75

Chesf

13.74

12.83

100.45

Furnas

8.01

13.42

71.73

Eletronuclear

0.37

2.16

17.49

Eletrosul

0.05

0.57

26.92

CGTEE

0.16

0.50

2.64

Amazonas GT

-

1.25

3.47

Itaipu Binacional

-

-

-

ED Acre

4.76

3.35

35.81

ED Alagoas

1.41

1.78

16.43

ED Amazonas Energia

9.39

5.58

502.12

ED Piauí

3.37

4.10

176.23

ED Rondônia

5.78

9.83

132.63

ED Roraima

0.05

0.09

12.56

CELG D

8.25

-

-

Furnas Subsidiaries

-

-

-

Eletrosul Subsidiaries

-

-

-

Other Companies (1)

0.90

0.99

-

(1) Furnas subsidiaries are Arara Azul; Bentevi; Ouro Verde I, II and II; Ventos de Sta Rosa, de Uirapuru e Angelim; Energia dos Ventos V, VI, VII, VII, VIII and IX; Transenergia Goiás e Brasil Ventos.

(2)Eletrosul subsidiaries are TSBE; TSLE; Uirapuru; Fronteira Oeste Transmissora; Eólica Hermenegildo I, II, III and Eólica Chuí.

(3) Including Cepel and Eletropar

(4) Others are: Environmental quality, infrastructure, "Luz Para Todos" (Light For All Program) and technological development.

 

53

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex III - 2Q17

Operating Information of the Subsidiaries

 

 

VI.2 New Investments

 

VI.2.1 Generation

 

VI.2.1.1 Integral Responsibility

Eletrobras Companies

Plant

Location
(State)

Investiment (R$ Million)

Installed Capacity (MW)

Energy Assured (MW)

Beginning of Operation

Beginning of Construction

End of Concession

RCE

FCE

Total

Up to 2Q17

MW Avg

Avg Price (R$/MWh)

MW Avg

Chesf

WPP Casa Nova I

BA

800.00

669.92

180

61.4

(1)

(2)

(2)

(2)

(2)

(2)

WPP Casa Nova II

BA

110.64

111.84

28

7.1

Dec-17

May/49 (3)

May/49 (3)

7.10

163.80

-

WPP Casa Nova III

BA

99.80

45.14

24

5.5

Dec-17

May/49 (3)

May/49 (3)

5.50

163.80

-

Furnas

PCH Anta

RJ/MG

(4)

(4)

28

15,9 (6)

GU1 e GU2: See (5)

Mar-07

-

97%

214.01

-

Eletronuclear

Angra 3

RJ

26.144 (7)

9,434

1,405

1,184

01-01-2024 (9)

Jul-08

Dec/63 (8)

n/a

n/a

n/a

Amazonas GT

UTE Mauá 3

AM

1,701.00

1,186

590.75

507.2

Jul-17

Sep-12

Nov-44

-

-

-

(1) The uncertainties associated with the construction of this undertaking , including those connected to the impossibility of energy distribution of SIN up to 2021, according to Technical Note 121/2016 r0 by ONS, dated Oct 3rd 2016, as a result, there is an unpredictability of its go live date.

(2) Wind farm project without grants and not-traded energy

(3) - According to MME Ordinance No. 220 of 05.26.2014 and MME Ordinance No. 225 of 05.28.2014.

(4) Includes Simplicio, which is already in operation.

(5) Scheduled date to begin commercial operation of the generating units of SHU Anta as Correspondence DE.E.026.2016 of June 23, 2016, sent to ANEEL: GU1 - 05.01.2018 and UG2 – 09.01.2018. It is worth mentioning that the contract supplier consortium was terminated.

(6) Assured energy corresponds to future commercial operation of Anta. It does not include the assured energy of Simplicio, reported in Section 1.2.

(7)It includes direct costs of R$ 21,051.2 million approved in RDE 1302.007/16 07.26.2016, setting the new date entry with indirect costs of R$ 26,522.00 million. Go live date 01/01/2024 according to RDE 1355 005/17 of 05/06/2017.

(8) No operating license for Angra 3. It is considered 40 years from 01.01.2021 by analogy with Angra 2.

(9) Go live date 01/01/2024 according to RDE 1355 005/17 of 05/06/2017.

 

 

54

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex III - 2Q17

Operating Information of the Subsidiaries

VI.2.1.2 Special Proposed Company

                            

SPE

Plant

Eletrobras Companies (%)

Location
(State)

Installed Capacity (MW)

Energy Assured
(MW)

Início da Operação

Beginning of Operation

End of Concession

Investiment
(R$ Million)

Working Schedule (%)

Partners

RCE

FCE

Total

Up to 2Q17

MW Average

Price Avg (R$/MWh)

MW Average

Norte Energia S.A. (2)

HPU Belo Monte

Eletronorte (19.98%)
Chesf (15%)
Eletrobras Holding (15%)

PA

11,233.10

4,571.00

Apr-16

Aug-11

Aug-45

35,937.94

32,865.34

93.15%

Petros (10.00%)
Belo Monte Part (10.00%)
Amazonas Energia (9.77%)
Others (20.25%)

70.00

117.74

30 (2)

Cia. Energética Sinop S.A.

HPU Sinop

Eletronorte (24.5%)
Chesf (24.5%)

MT

408.00

239.8

Dec-18

Dec-13

Dec-47

3,003.16

1640.51

90.20%

EDF UTE Norte Fluminense (51.0%)

190.94

141.57

10.62

ESBR Participações S.A.

HPU Jirau

Chesf (20%)
Eletrosul (20%)

RO

3,750.00

2205.1

Sep-13

Dec-09

Aug-43

19,562.00

19,194.50

100.00

Suez Energy (40%)
Mizha Energia (20%)
Eletrosul (20%)

1,641.26

111.49

553.46

Acauã Energia S.A. (3)

WPP Acauã

Chesf (99.93%)

BA

6.00

3.1

Jan-18

mai/15

Apr-49

46.60

34.74

80.40%

Sequóia (0.00668%)

3.10

134.69

-

Angical 2 Energia S.A. (3)

WPP Angical 2

Chesf (99.96%)

BA

10.00

5.1

Oct-17

mai/15

Apr-49

68.40

lk

78.20%

Sequóia (0.04%)

5.10

134.69

-

Arapapá Energia S.A. (3)

WPP Arapapá

Chesf (99.9%)

BA

4.00

2.2

Oct-17

mai/15

Apr-49

36.80

21.31

64.60%

Sequóia (0.1%)

2.20

134.69

-

Caititú 2 Energia S.A. (3)

WPP Caititú 2

Chesf (99.96%)

BA

10.00

5.1

May-18

mai/15

Apr-49

71.50

46.40

65.20%

Sequóia (0.04%)

5.10

134.69

-

Caititú 3 Energia S.A. (3)

WPP Caititú 3

Chesf (99.96%)

BA

10.00

4.7

Jun-18

mai/15

Apr-49

70.10

45.10

65.60%

Sequóia (0.04%)

4.70

134.69

-

Carcará Energia S.A. (3)

WPP Carcará

Chesf (99.96%)

BA

10.00

4.6

Apr-18

mai/15

Apr-49

72.60

54.50

75.40%

Sequóia (0.04%)

4.60

134.69

-

Coqueirinho 2 Energia S.A. (3)

WPP Coqueirinho 2

Chesf (99.98%)

BA

16.00

8.5

Oct-17

mai/15

Jun-49

120.05

94.60

81.20%

Sequóia (0.0238%)

8.50

158.02

-

Corrupião 3 Energia S.A. (3)

WPP Corrupião 3

Chesf (99.96%)

BA

10.00

4.2

Apr-18

mai/15

Apr-49

74.00

49.90

69.60%

Sequóia (0.04%)

4.20

134.69

-

Papagaio Energia S.A. (3)

WPP Papagaio

Chesf (99.96%)

BA

10.00

4.9

Feb-18

mai/15

Jun-49

75.80

54.08

67.50%

Sequóia (0.04%)

4.90

157.41

-

Tamanduá Mirim 2 Energia S.A. (3)

WPP Tamanduá Mirim 2

Chesf (83.01%)

BA

16.00

8

Jan-18

May-15

Jun-49

121.40

88.56

72.70%

Sequóia (16.99%)

8.00

154.11

-

Teiú 2 Energia S.A. (3)

WPP Teiú 2

Chesf (99.95%)

BA

8.00

4.2

Nov-17

Jun-15

Apr-49

57.50

36.80

69.00%

Sequoia (0.05%)

4.20

134.69

-

Empresa de Energia São Manoel S.A.

HPU São Manoel

Furnas (33,33%)

MT/PA

700.00

421.70

Oct-17

Aug-14

Apr-49

0.00

0.00

0.00%

EDP – Energias do Brasil S.A.(33.33%)
CWEI (33.33%)

0.00

0.00

-

Central Geradora Eólica Famosa I S.A.

Famosa I

Furnas (49%)

RN

22.50

11.10

Oct-18

Aug-16

mai/47 

0.00

0.00

0.00%

PF Participações (51.00%)

0.00

0.00

-

Central Geradora Eólica Pau Brasil S.A.

Pau Brasil

Furnas (49%)

CE

15.00

7.70

Oct-18

Aug-16

mar/47 

0.00

0.00

0.00%

PF Participações (51.00%)

0.00

0.00

-

Central Geradora Eólica Rosada S.A.

Rosada

Furnas (49%)

RN

30.00

13.40

Oct-18

Aug-16

May-48

0.00

0.00

0.00%

PF Participações (51.00%)

0.00

0.00

-

Central Geradora Eólica São Paulo S.A.

São Paulo

Furnas (49%)

CE

17.50

8.10

Oct-18

Aug-16

mar/47 

0.00

0.00

0.00%

PF Participações (51.00%)

0.00

0.00

-

Energia dos Ventos V S.A.

São Januário

Furnas (99,99%)

CE

19.20

9.00

Nov-19

Jan-17

Jul-47

0.00

0.00

0.00%

Alupar(0 %)
Central Eólica Goiabeira (0.01%)

0.00

0.00

-

Energia dos Ventos VI S.A.

Nossa Senhora de Fátima

Furnas (99,99%)

CE

28.80

12.80

Nov-19

Jan-17

Aug-47

0.00

0.00

0.00%

Alupar(0 %)
Central Eólica Goiabeira (0.01%)

0.00

0.00

-

Energia dos Ventos VII S.A.

Jandaia

Furnas (99,99%)

CE

28.80

14.10

Nov-19

Jan-17

Aug-47

0.00

0.00

0.00%

Alupar(0 %)
Central Eólica Goiabeira (0.01%)

0.00

0.00

-

Energia dos Ventos VIII S.A.

São Clemente

Furnas (99,99%)

CE

19.20

9.30

Nov-19

Jan-17

Jul-47

0.00

0.00

0.00%

Alupar(0%)
Central Eólica Goiabeira (0.01%)

0.00

0.00

-

Energia dos Ventos IX S.A.

Jandaia I

Furnas (99,99%)

CE

19.20

9.90

Nov-19

Jan-17

Jul-47

0.00

0.00

0.00%

Alupar(0 %)
Central Eólica Goiabeira (0.01%)

0.00

0.00

-

Bom Jesus Eólica S.A.

Bom Jesus

Furnas (49%)

CE

18.00

8.10

Dec-18

Aug-16

Apr-49

0.00

0.00

0.00%

Fundo de Investimento em Participações Caixa Milão (50.99%)
Central Eólica Bom Jesus Ltda. (0.01%)

0.00

0.00

-

Cachoeira Eólica S.A.

Cachoeira

Furnas (49%)

CE

12.00

5.00

Dec-18

Aug-16

Apr-49

0.00

0.00

0.00%

Fundo de Investimento em Participações Caixa Milão (50.99%)
Central Eólica Bom Jesus Ltda. (0.01%)

0.00

0.00

-

Pitimbu Eólica S.A.

Pitimbu

Furnas (49%)

CE

18.00

7.20

Dec-18

Aug-16

Mar-49

0.00

0.00

0.00%

Fundo de Investimento em Participações Caixa Milão (50.99%)
Central Eólica Bom Jesus Ltda. (0.01%)

0.00

0.00

-

São Caetano Eólica S.A.

São Caetano

Furnas (49%)

CE

25.20

11.00

Dec-18

Aug-16

Apr-49

0.00

0.00

0.00%

Fundo de Investimento em Participações Caixa Milão (50.99%)
Central Eólica Bom Jesus Ltda. (0.01%)

0.00

0.00

-

São Caetano I Eólica S.A.

São Caetano I

Furnas (49%)

CE

18.00

7.70

Dec-18

Aug-16

Apr-49

0.00

0.00

0.00%

Fundo de Investimento em Participações Caixa Milão (50.99%)
Central Eólica Bom Jesus Ltda. (0.01%)

0.00

0.00

-

São Galvão Eólica S.A.

São Galvão

Furnas (49%)

CE

22.00

9.50

Dec-18

Aug-16

Mar-49

0.00

0.00

0.00%

Fundo de Investimento em Participações Caixa Milão (50.99%)
Central Eólica Bom Jesus Ltda. (0.01%)

0.00

0.00

-

Carnaúba I Eólica S.A.

Carnaúba I

Furnas (49%)

RN

22.00

9.40

Dec-18

Aug-16

Jul-49

0.00

0.00

0.00%

Fundo de Investimento em Participações Caixa Milão (50.99%)
Central Eólica Bom Jesus Ltda. (0.01%)

0.00

0.00

-

Carnaúba II Eólica S.A.

Carnaúba II

Furnas (49%)

RN

18.00

7.30

Dec-18

Aug-16

Jul-49

0.00

0.00

0.00%

Fundo de Investimento em Participações Caixa Milão (50.99%)
Central Eólica Bom Jesus Ltda. (0.01%)

0.00

0.00

-

Carnaúba III Eólica S.A.

Carnaúba III

Furnas (49%)

RN

16.00

7.50

Dec-18

Aug-16

Jul-49

0.00

0.00

0.00%

Fundo de Investimento em Participações Caixa Milão (50.99%)
Central Eólica Bom Jesus Ltda. (0.01%)

0.00

0.00

-

Carnaúba V Eólica S.A.

Carnaúba V

Furnas (49%)

RN

24.00

10.10

Dec-18

Aug-16

Jul-49

0.00

0.00

0.00%

Fundo de Investimento em Participações Caixa Milão (50.99%)
Central Eólica Bom Jesus Ltda. (0.01%)

0.00

0.00

-

Cervantes I Eólica S.A.

Cervantes I

Furnas (49%)

RN

16.00

7.10

Dec-18

Aug-16

Jul-49

0.00

0.00

0.00%

Fundo de Investimento em Participações Caixa Milão (50.99%)
Central Eólica Bom Jesus Ltda. (0.01%)

0.00

0.00

-

Cervantes II Eólica S.A.

Cervantes II

Furnas (49%)

RN

12.00

5.60

Dec-18

Aug-16

Jul-49

0.00

0.00

0.00%

Fundo de Investimento em Participações Caixa Milão (50.99%)
Central Eólica Bom Jesus Ltda. (0.01%)

0.00

0.00

-

Punaú I Eólica S.A.

Punaú I

Furnas (49%)

RN

24.00

11.00

Dec-18

Aug-16

Jul-49

0.00

0.00

0.00%

Fundo de Investimento em Participações Caixa Milão (50.99%)
Central Eólica Bom Jesus Ltda. (0.01%)

0.00

0.00

-

Geradora Eólica Arara Azul S.A.

Arara Azul

Furnas (90%)

RN

27.50

10.70

Oct-18

Jan-17

Nov-49

0.00

0.00

0.00%

Eólica Tecnologia Ltda (7.00%)
Ventos Tecnologia Elétrica Ltda (2.99%)
Central Eólica Arara Azul Ltda (0.01%)

0.00

0.00

-

Geradora Eólica Bentevi S.A.

Bentevi

Furnas (90%)

RN

15.00

5.70

Oct-18

Jan-17

Nov-49

0.00

0.00

0.00%

Eólica Tecnologia Ltda (7.00%)
Ventos Tecnologia Elétrica Ltda (2.99%)
Central Eólica Bentevi Ltda (0.01%)

0.00

0.00

-

Geradora Eólica Ouro Verde I S.A.

Ouro Verde I

Furnas (90%)

RN

27.50

10.70

Oct-18

Jan-17

Nov-49

0.00

0.00

0.00%

Eólica Tecnologia Ltda (7.00%)
Ventos Tecnologia Elétrica Ltda (2.99%)
Central Eólica Ouro Verde I Ltda (0.01%)

0.00

0.00

-

Geradora Eólica Ouro Verde II S.A.

Ouro Verde II

Furnas (90%)

RN

30.00

11.20

Oct-18

Jan-17

Nov-49

0.00

0.00

0.00%

Eólica Tecnologia Ltda (7.00%)
Ventos Tecnologia Elétrica Ltda (2.99%)
Central Eólica Ouro Verde II Ltda (0.01%)

0.00

0.00

-

Geradora Eólica Ouro Verde III S.A.

Ouro Verde III

Furnas (90%)

RN

25.00

9.40

Oct-18

Jan-17

Nov-49

0.00

0.00

0.00%

Eólica Tecnologia Ltda (7.00%)
Ventos Tecnologia Elétrica Ltda (2.99%)
Central Eólica Ouro Verde III (0.01%)

0.00

0.00

-

Geradora Eólica Ventos de Santa Rosa S.A.

Santa Rosa

Furnas (90%)

CE

20.00

8.40

Oct-18

Jan-17

Oct-49

0.00

0.00

0.00%

Eólica Tecnologia Ltda (7.00%)
Ventos Tecnologia Elétrica Ltda (2.99%)
Central Eólica Santa Rosa Ltda (0.01%)

0.00

0.00

-

Geradora Eólica Ventos de Uirapuru S.A.

Uirapuru

Furnas (90%)

CE

28.00

12.60

Oct-18

Jan-17

Oct-49

0.00

0.00

0.00%

Eólica Tecnologia Ltda (7.00%)
Ventos Tecnologia Elétrica Ltda (2.99%)
Central Eólica Uirapuru Ltda (0.01%)

0.00

0.00

-

Geradora Eólica Ventos do Angelim S.A.

Ventos de Angelim

Furnas (90%)

CE

24.00

10.30

Oct-18

Jan-17

Nov-49

0.00

0.00

0.00%

Eólica Tecnologia Ltda (7.00%)
Ventos Tecnologia Elétrica Ltda (2.99%)
Central Eólica Angelim Ltda (0.01%)

0.00

0.00

-

Consórcio Serra do Mel

Serra do Mel I

Furnas (90%)

RN

28.00

13.00

Nov-18

May-18

Oct-49

0.00

0.00

0.00%

Eólica Tecnologia Ltda (9.99%)
Gestamp Eólica Brasil S.A. (0.01%)

0.00

0.00

-

Consórcio Serra do Mel

Serra do Mel II

Furnas (90%)

RN

28.00

12.80

Nov-18

Jun-18

Oct-49

0.00

0.00

0.00%

Eólica Tecnologia Ltda (9.99%)
Gestamp Eólica Brasil S.A. (0.01%)

0.00

0.00

-

Consórcio Serra do Mel

Serra do Mel III

Furnas (90%)

RN

28.00

12.50

Nov-18

Aug-18

Nov-49

0.00

0.00

0.00%

Eólica Tecnologia Ltda (9.99%)
Gestamp Eólica Brasil S.A. (0.01%)

0.00

0.00

-

Geradora Eólica Itaguaçu da Bahia SPE S.A.

Itaguaçu da Bahia

Furnas (49%)

BA

28.00

14.00

Feb-19

May-18

Sep-49

0.00

0.00

0.00%

Salus Fundo de Investimento em Participações (49.00%)
Casa dos Ventos Energias Renováveis S.A. (2.00%)

0.00

0.00

-

Geradora Eólica Ventos de Santa Luiza SPE S.A.

Ventos de Santa Luiza

Furnas (49%)

BA

28.00

14.20

Feb-19

Jan-17

Sep-49

0.00

0.00

0.00%

Salus Fundo de Investimento em Participações (49.00%)
Casa dos Ventos Energias Renováveis S.A. (2.00%)

0.00

0.00

-

Geradora Eólica Ventos de Santa Madalena SPE S.A.

Ventos de Santa Madalena

Furnas (49%)

BA

28.00

14.70

Feb-19

Jan-17

Sep-49

0.00

0.00

0.00%

Salus Fundo de Investimento em Participações (49.00%)
Casa dos Ventos Energias Renováveis S.A. (2.00%)

0.00

0.00

-

Geradora Eólica Ventos de Santa Marcella SPE S.A.

Ventos de Santa Marcella

Furnas (49%)

BA

28.00

13.60

Feb-19

Jan-17

Sep-49

0.00

0.00

0.00%

Salus Fundo de Investimento em Participações (49.00%)
Casa dos Ventos Energias Renováveis S.A. (2.00%)

0.00

0.00

-

Geradora Eólica Ventos de Santa Vera SPE S.A.

Ventos de Santa Vera

Furnas (49%)

BA

28.00

15.20

Feb-19

Jan-17

Sep-49

0.00

0.00

0.00%

Salus Fundo de Investimento em Participações (49.00%)
Casa dos Ventos Energias Renováveis S.A. (2.00%)

0.00

0.00

-

Geradora Eólica Ventos de Santo Antônio SPE S.A.

Ventos de Santo Antônio

Furnas (49%)

BA

28.00

16.10

Feb-19

Jan-17

Sep-49

0.00

0.00

0.00%

Salus Fundo de Investimento em Participações (49.00%)
Casa dos Ventos Energias Renováveis S.A. (2.00%)

0.00

0.00

-

Geradora Eólica Ventos de São Bento SPE S.A.

Ventos de São Bento

Furnas (49%)

BA

28.00

14.40

Feb-19

Jan-17

Sep-49

0.00

0.00

0.00%

Salus Fundo de Investimento em Participações (49.00%)
Casa dos Ventos Energias Renováveis S.A. (2.00%)

0.00

0.00

-

Geradora Eólica Ventos de São Cirilo SPE S.A.

Ventos de São Cirilo

Furnas (49%)

BA

28.00

14.70

Feb-19

Jan-17

Sep-49

0.00

0.00

0.00%

Salus Fundo de Investimento em Participações (49.00%)
Casa dos Ventos Energias Renováveis S.A. (2.00%)

0.00

0.00

-

Geradora Eólica Ventos de São João SPE S.A.

Ventos de São João

Furnas (49%)

BA

28.00

15.00

Feb-19

Jan-17

Sep-49

0.00

0.00

0.00%

Salus Fundo de Investimento em Participações (49.00%)
Casa dos Ventos Energias Renováveis S.A. (2.00%)

0.00

0.00

-

Geradora Eólica Ventos de São Rafael SPE S.A.

Ventos de São Rafael

Furnas (49%)

BA

28.00

13.80

Feb-19

Jan-17

Sep-49

0.00

0.00

0.00%

Salus Fundo de Investimento em Participações (49.00%)
Casa dos Ventos Energias Renováveis S.A. (2.00%)

0.00

0.00

-

(1) Due to the plant motorization and current injunction limiting the energy revenues to a percentage of the physical guarantee of commercial operations, it is not possible to calculate in advance the tradable energy. Nowadays, currently insatalled capacity in commercial operation is 2,677.5 MW.

(2) It includes 20% FCE and 10% Self-producer

(3) Low evolution compared with the previous quarter, as a result of the work stoppage.

 

55

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex III - 2Q17

Operating Information of the Subsidiaries

VI.2.2 Transmission

            
               

VI.2.2.1 Integral Responsability

            
               

VI.2.2.1.1 Transmission Lines

            

Eletrobras Companies

(From - To)

Total Investment (R$ Million)

Lines Extension (km)

Tension (kV)

Beginning of Operation

End of Concession

AAR (R$ Million)

Chesf

Eunápolis-Teixeira Freitas II C1

30.09

145.00

230

Jun-19

Oct-38

7.02

Funil-Itapebi C3

41.07

223.00

230

Nov-20

Apr-37

6.31

Eunápolis-Teixeira Freitas II C2

44.15

152.00

230

Dec-17

Aug-39

7.44

Pau Ferro-Santa Rita II

36.11

96.70

230

Oct-20

Aug-39

6.16

Paraíso-Açu II

84.89

123.00

230

Sep-20

Nov-40

4.90

Açu II-Mossoró II

69.00

0

Sep-20

Nov-40

Morro do Chapéu II-Irecê

22.13

65.00

230

Sep-17

Oct-41

5.71

Teresina II-Teresina III

13.76

26.00

230

Nov-17

Dec-41

11.56

Recife II-Suape II C2

41.91

44.00

230

Jan-21

Dec-41

7.86

Camaçari IV-Sapeaçu

84.29

105.00

230

Sep-21

Dec-41

11.85

Sapeaçu-Sto.Antonio de Jesus C3

31.00

230

Nov-20

Dec-41

Jardim-N Sra do Socorro

13.60

1.30

230

Jun-18

May-42

20.09

Messias-Maceió II

20.00

230

Jul-19

May-42

Camaçari IV-Pirajá

47.07

45.00

230

Dec-19

May-42

12.10

Pituaçú-Pirajá

5.00

230

Dec-19

May-42

Mossoró II-Mossoró IV

81.74

40.00

230

Sep-17

Jun-42

16.44

Russas II-Banabuiu C2

110.00

230

Nov-19

Jun-42

Furnas

LT Mascarenhas – Linhares e SS Linhares

0

0.00

99

Aug-00

May-19

0.05

LT Xavantes – Pirineus (1)

0

0.00

50

Aug-00

May-18

0.05

Eletrosul*

Secc. Jorge Lacerda A - Palhoça, in SS Garopaba

9.90

5.40

138

Dec-18

Dec-42

1.19

Concession contract 001/2015 (Several enterprises in RS)

**

1802.00

230 e 525

**

Mar-45

225.98

(1) The transmission line was energized in 03/25/2016, the detached form the circuit 1 (CELG), and still depends on the completion of the line inputs at substations associated with the project.

* The AAR of the enterprises in Lot A of Aneel Auction 004/2014 (Concession 001/2015) is at it historical acquisition price.

** In 2016, the company promoted a public call to select investors interested in the shareholding of the concession contract 001/2015, which budget forecast is approximately R$ 3.3 billion (Lines and SS). There was a proposal which is still under negotiation. The expenditures up to Mar/17, considering lines and substations, sum up R$ 105.6 million.

 

56

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex III - 2Q17

Operating Information of the Subsidiaries

VI.2.2.1.2 Substations

            

Eletrobras Companies

SS

Investment Total (R$ Million)

Transformation Capacity (MVA)

Location (State)

Beginning of Operation

End of Concession

AAR (R$ Millions)

Eletronorte (1)

SS Nova Mutum - Etapa TR3

0.00

33

AC

Jan-17

Dec-42

-

Chesf

SS 230/69 kv Morro do Chapéu II

24.33

150

BA

Sep-17

Oct-41

(*)

SS 230/69 kv Teresina III

29.21

400

PI

Nov-17

Dec-41

(*)

SS 230/69 kv N.S. Socorro

94.43

300

SE

Jun-18

May-42

(*)

SS 230/69 kv Maceió II

400

AL

Jul-19

May-42

(*)

SS 230/138 kv Poções II

200

BA

Jun-18

May-42

(*)

SS 230/69 kv Pirajá

30.57

360

BA

Dec-19

May-42

(*)

SS 230/69 kv Jaboatão II

68.77

360

PE

Jul-18

Jun-42

5,419,435.29

SS 230/69 kv Mossoró IV

46.18

100

RN

Sep-17

Jun-42

(*)

SS 230/138 kV Teixeira de Freitas II

17.91

100

BA

Jun-19

Oct-38

(*)

Eletrosul (2)

Garopaba - Implementation of two EL modules

7.48

0.00

SC

Dec-18

Dec-42

0.9099

Canoinhas - Substitution of the 3rd Autotransf. 230/138 kV (75 MVA per 150 MVA)

8.78

75.00

SC

Jan-18

Dec-42

1.4270

Santo Ângelo - 3rd bank of autotransformers 525/230kV

44.30

672.00

RS

Feb-18

Dec-42

7.5795

Tapera - Installation capacitors banks 230kV - 50 MVAr

7.70

-

RS

Jan-18

Dec-42

1.2413

Dourados - Two capacitors banks 230kV of 50 Mvar

13.35

-

MS

Apr-18

Dec-42

2.5110

Dourados - Installation of spare processing unit 230/138kV

0.86

75

MS

Aug-17

Dec-42

0.2208

Biguaçu - Capacitor bank 230 kV, 100 MVAr and connection 230kV

9.28

-

SC

Nov-18

Dec-42

1.40

SS Nova Petrópolis - Installation of the 2nd transformer 230/69kV

14.62

83

RS

Sep-18

Oct-40

1.53

Concession contract 001/2015 (Several enterprises in RS)

**

4781

RS

**

Mar-45

110.02

(1) The additional revenue parcel associated with the reinforcements will be incorporated into the AAR of the transmission concession companies in the annual readjustment after their go-lives.

 

(*) The substation AAR is being informed jointly with the TLs, according to the concession agreement.

(**) In 2016, the company promoted a public call to select investors interested in the shareholding of the concession contract 001/2015, which budget forecast is approximately R$ 3.3 billion (Lines and SS). There was a proposal which is still under negotiation. The expenditures up to Mar/17, considering lines and substations, sum up R$ 110.1 million.

(2) The AAR of the enterprises in Lot A of Aneel Auction 004/2014 (Concession 001/2015) is at it historical acquisition price.

 

57

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex III - 2Q17

Operating Information of the Subsidiaries

VI.2.2.2 Special Proposed Company

                  
                     

VI.2.2.2.1 Transmission Lines

                  

SPC

From - To

Eletrobras Companies (%)

Investiment (R$ Million)

Lines Extension (km)

Tension (kV)

Partners

Beginning of Operation

End of Concession

AAR (R$ Million)

Total

Up to 2Q17

Transnorte Energia S.A. (*)

Eng. Lechuga - Equador

Eletronorte (49%)

488.58

170.86

400.3

500

-

Oct-19

Jan-42

56.68

Equador - Boa Vista

399.57

0.00

315.20

44.63

Belo Monte Transmissora de Energia SPE S.A.

TL in continuous current of ±800 kV Xingu - Estreito.

Eletronorte (24.5%)
Furnas (24.5%)

2,620.00

2,405.00

2092

±800

State Grid (51% e Eletronorte (24m5%)

Feb-18

Jun-44

434,65
(out/13)

TDG Transmissora Delmiro Gouveia S.A.

LT São Luiz II/ São Luiz III

Chesf (49%)

52.00

34.00

39

230

51% ATP Engenharia Ltda

Sep-18

Jul-40

2.18

Transenergia Goiás S.A. (1)

Serra da Mesa – Niquelândia

Furnas (99%)

(1)

0.00

100

230

J.Malucelli (1%)

Jul-17

Sep-39

6,78 (jul/16)

Mata de Santa Genebra Transmissora S.A. (1)

Itatiba – Bateias

Furnas (49.9%)

(1)

0.00

399

500

Copel (50,1%)

May-18

May-44

57,34 (nov/13)

Araraquara II - Itatiba

207

500

May-18

Araraquara II - Fernão Dias

241

500

May-18

Vale do São Bartolomeu Transmissora de Energia S.A. (1)

Luziânia - Brasília Leste Circ 1 Luziânia - Brasília Leste Circ 2

Furnas (39%)

(1)

0.00

67

500

FIP Caixa Milão (51% e CELG (10%)

May-18

Oct-43

11,22 (jul/13)

 

67

500

Oct-17

Oct-43

8,01 (jul/13)

Fronteira Oeste Transmissora de Energia S.A.

Santo Ângelo/Maçambará
Pinhalzinho/Foz do Chapecó, double circuit Expansions SS Maçarambá, Foz do Chapecó e Sto Angelo

Eletrosul (51%)

143.49

22.49

199
72

230
230

CEEE 49%

Mar/19
Nov/17 e Ago/18

Jan-44

8.69

Paraíso Transmissora de Energia S.A. (2)

Paraíso 2-Chapadão;
Campo Grande 2-Paraíso 2;
Portioning LT Chapadão - Campo Grande 2 - C1 na SE Paraíso 2

Eletrosul (100%)

133.97

6.52

65
217
1

230

-

(2)

Mar-45

11.76

(1) Investment Total Amount on the basis of the development of the business plan.

(2) Start forecast is under reevaluation due to a public call to investors. AAR Reference date: 06/30/2014

(*) AAR - Cycle 2017/2018 - To the AAR division was used the modules list provided by ANEEL (NT 0183-2017-SGT). Previously, the cost of building sections was used for the AAR division.

 

 

58

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex III - 2Q17

Operating Information of the Subsidiaries

VI.2.2.2.2 Substations

SPC

SS

Transnorte Energia S.A. (*)

SS Boa Vista - CER

SS Engenheiro Lechuga

SS Equador

SS Boa Vista

Mata de Santa Genebra Transmissora S.A.

SS Santa Bárbara D’Oeste 440 kV, Static Compensator (-300,+300) Mvar;
SS Itatiba 500 kV, Static Compensator
(-300,+300) Mvar.

SS 500/440 kV Fernão Dias 1.200 MVA - 1st autotransformer bank

SS 500/440 kV Fernão Dias 2.400 MVA
2nd and 3rs autotransformers bank

Vale do São Bartolomeu Transmissora de Energia S.A.

SS Brasília Leste

Belo Monte Transmissora de Energia S.A.

Converter Station CA/CC,±800 kV, 4.000 MW, with SS 500 kV Xingu;

Converter Station CA/CC, ±800 kV, 3.850 MW, with SS 500 kV Estreito

ETAU (**)

Expansion SS Lagoa Vermelha II - 50 Mvar

Fronteira Oeste Transmissora de Energia S.A. (1)

Pinhalzinho, em 230/138 kV (ATF1, ATF2 e ATF3);
Expansions SS Maçarambá, Foz do Chapecó e Santo Angelo.

Paraíso Transmissora de Energia S.A. (***)

Campo Grande 2 EL 230 PAR2;
Chapadão EL PAR2;
Paraíso 2, 230/138 kV.

Transmissora Sul Litorânea de Energia - TSLE

Expansion SS Povo Novo 525/230 kV

(*) AAR - Cycle 2017/2018 - To the AAR division was used the modules list provided by ANEEL (NT 0183-2017-SGT). Previously, the cost of building sections was used for the AAR division.

 

(**) The asset will be transferred to Eletrobras, as approved at the 147th Extraordinary General Meeting (EGM) held on 19 April, 2017.

 

(***) Start forecast is under reevaluation due to a public call to investors. AAR Reference date: 06/30/2014

 

(1) Investment Total Amount on the basis of the development of the business plan.

(2) Converter station has 4,000 MW of transformation capacity.

(3) Converter station has 3,850 MW of transformation capacity.

(4) The AAR and the total investments of the substations are being informed with the TL, according to the concession contract.

 

59

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex III - 2Q17

Operating Information of the Subsidiaries

VII. SPEs Data

                        
                         

VII.1 Operational Data

                        
                         

VII.1.1 Generation

                        
                         

VII.1.1.1 Operational assets and generated energy

                    

SPE

Plant

Eletrobras Companies (%)

Location (State)

Installed Capacity(MW)

Energy Assured (MW Avg)
(MW Médio)

Generated Energy MWh

Beginning of Operation

End of Concession

RCE

FCE

1Q17

2Q17

MW Average

Avg Price (R$/ MWh)

MW Average

EAPSA - Energia Águas Da Pedra S.A.

HPU Dardanelos

Eletronorte (24,5%)
Chesf (24,5%)

MT

261.0

154.9

501,329

492,622

Aug-11

Jul-42

154.9

206.88

-

Amapari Energia S.A. (1) (2)

TPP Serra do Navio

Eletronorte (49%)

AP

23.3

21.0

-

-

Jun-08

May-37

-

-

-

Brasventos Miassaba 3 Geradora de Energia S.A

WPP Miassaba 3

Eletronorte (24,5%)
Furnas (24,5%)

RN

68.5

22.8

35,017

30,154

May-14

Aug-45

-

-

-

Brasventos Eolo Geradora de Energia S.A.

WPP Rei dos Ventos 1

Eletronorte (24,5%)
Furnas (24,5%)

RN

58.5

21.9

35,204

24,866

May-14

Dec-45

-

-

-

Rei dos Ventos 3 Geradora de Energia S.A.

WPP Rei dos Ventos 3

Eletronorte (24,5%)
Furnas (24,5%)

RN

60.1

21.1

30,487

27,315

May-14

Dec-45

-

-

-

ESBR Participações S.A. (6)

HPU Jirau

Chesf (20%)
Eletrosul (20%)

RO

3,750.0

2,205.1

5,148,063

5,646,699

Sep-13

Aug-43

1,641.3

111.49

26

Norte Energia S.A. (3)

HPU B. Monte

Chesf (15%)
Eletronorte (19,98%)
Eletrobras Holding (15%)

PA

11,233.1

4,571.0

5,214,020

6,540,259

abr/16

Aug-45

(5)

124.05

30,00 (4)

Pedra Branca S.A.

Pedra Branca

Chesf (49%)

BA

30.0

12.9

22,453

35,531

Mar-13

Feb-46

12.2

203.32

3.1

São Pedro do Lago S.A.

São Pedro do Lago

Chesf (49%)

BA

30.0

13.5

20,603

32,987

Mar-13

Feb-46

13.2

203.32

-

Sete Gameleiras S.A.

Sete Gameleiras

Chesf (49%)

BA

30.0

12.6

21,342

32,073

Mar-13

Feb-46

12.5

203.32

-

Baraúnas I Energética S.A.

WPP Baraúnas I

Chesf (49%)

BA

32.9

12.4

23,189

33,352

Nov-15

Feb-49

12.2

147.21

-

Mussambê Energética S.A.

WPP Mussambê

Chesf (49%)

BA

32.9

11.5

21,295

33,907

Oct-15

Feb-49

11.4

147.21

-

Morro Branco I Energética S.A.

WPP Morro Branco I

Chesf (49%)

BA

32.9

12.7

22,083

34,052

Nov-15

Feb-49

12.5

147.21

-

Banda de Couro Energética S.A.

WPP Banda de Couro

Chesf (1,7%)

BA

32.9

12.8

19,356

31,488

Mar-16

Jun-49

-

153.86

96

Baraúnas II Energética S.A.

WPP Baraunas II

Chesf (1,5%)

BA

25.9

10.7

16,116

24,076

Mar-16

Jul-49

-

151.57

95

V. de Santa Joana IX Energia Renováveis S.A. (7)

Santa Joana IX

Chesf (49%)

PI

29.6

15.8

10,216

30,407

Aug-15

Aug-35

11.0

139.79

16.46

V. de Santa Joana X Energia Renováveis S.A. (7)

Santa Joana X

Chesf (49%)

PI

29.6

16.0

11,751

31,574

Jul-15

Aug-35

11.6

139.79

15.00

V. de Santa Joana XI Energia Renováveis S.A. (7)

Santa Joana XI

Chesf (49%)

PI

29.6

16.0

10,846

29,225

Jul-15

Aug-35

12.4

139.79

11.88

V. de Santa Joana XII Energia Renováveis S.A. (7)

Santa Joana XII

Chesf (49%)

PI

28.9

16.9

17,489

36,218

Jul-15

Aug-35

13.9

139.79

9.47

V. de Santa Joana XIII Energia Renováveis S.A. (7)

Santa Joana XIII

Chesf (49%)

PI

29.6

16.0

13,173

30,336

Jul-15

Aug-35

11.2

139.79

16.25

V. de Santa Joana XV Energia Renováveis S.A. (7)

Santa Joana XV

Chesf (49%)

PI

28.9

16.2

15,064

34,849

Jul-15

Aug-35

13.9

139.79

7.41

V. de Santa Joana XVI Energia Renováveis S.A. (7)

Santa Joana XVI

Chesf (49%)

PI

28.9

17.4

14,707

35,674

Jul-15

Aug-35

13.5

139.79

12.07

V. de Santa Joana I Energia Renováveis S.A. (8)

WPP Santa Joana I

Chesf (49%)

PI

28.9

15.0

15,214

32,378

Jan-16

Dec-35

15.81

167.45

-2,67 (3)

V. de Santa Joana III Energia Renováveis S.A. (8)

WPP Santa Joana III

Chesf (49%)

PI

29.6

13.4

9,828

26,125

Mar-16

Dec-35

16.13

166.97

-9,70 (3)

V. de Santa Joana IV Energia Renováveis S.A. (8)

WPP Santa Joana IV

Chesf (49%)

PI

28.9

14.2

14,594

31,058

Jan-16

Dec-35

12.65

167.21

5.63

V. de Santa Joana V Energia Renováveis S.A. (8)

WPP Santa Joana V

Chesf (49%)

PI

28.9

15.7

13,339

32,474

Jan-16

Dec-35

12.84

167.17

9.55

V. de Santa Joana VII Energia Renováveis S.A. (8)

WPP Santa Joana VII

Chesf (49%)

PI

27.2

14.9

14,810

33,665

Jan-16

Dec-35

14.13

167.20

5.37

V. de Santo Augusto IV Energia Renováveis S.A. (8)

WPP Santo Augusto IV

Chesf (49%)

PI

28.9

15.5

14,267

33,036

Feb-16

Dec-35

14.48

165.46

4.52

U.E.E. Caiçara I S.A. (9)

WPP Caiçara I

Chesf (49%)

RN

27.0

15.1

24,990

21,795

Nov-15

Jun-47

14.48

155.89

4.10

U.E.E. Caiçara II S.A. (9)

WPP Caiçara II

Chesf (49%)

RN

18.0

9.6

16,809

15,443

Nov-15

Jul-47

9.54

155.84

0.60

U.E.E. Junco I S.A. (9)

WPP Junco I

Chesf (49%)

RN

24.0

13.1

21,278

18,693

Nov-15

Jul-47

12.79

157.01

2.40

U.E.E. Junco II S.A (9)

WPP Junco II

Chesf (49%)

RN

24.0

13.3

20,968

18,750

Nov-15

Jul-47

12.52

156.20

5.90

Eólica Serra das Vacas I S.A. (10)

Serra das Vacas I

Chesf (49%)

PE

23.9

12.2

25,704

23,368

Dec-15

Jun-49

12.20

155.89

-

Eólica Serra das Vacas II S.A. (10)

Serra das Vacas II

Chesf (49%)

PE

22.3

9.9

22,544

19,416

Dec-15

Jun-49

9.90

155.48

-

Eólica Serra das Vacas III S.A. (10)

Serra das Vacas III

Chesf (49%)

PE

22.2

11.0

24,229

18,390

Dec-15

Jun-49

11.00

155.98

-

Eólica Serra das Vacas IV S.A. (10)

Serra das Vacas IV

Chesf (49%)

PE

22.3

10.5

23,597

20,176

Dec-15

Jun-49

10.50

156.05

-

Enerpeixe S.A.

HPU Peixe Angical

Furnas (40%)

TO

498.8

280.5

411,981

346,571

Jun-06

Nov-36

15,613.00

156.00

439,574.00

Baguari Geração de Energia S.A.

HPU Baguari

Furnas (15%)

MG

140.0

80.0

47,014

70,284

Sep-09

Aug-41

110.00

216.00

110.00

Retiro Baixo Energética S.A.

HPU Retiro Baixo

Furnas (49%)

MG

82.0

38.5

43,585

14,889

Mar-10

Aug-41

105.00

105.00

3.00

Foz de Chapecó Energia S.A.

HPU Foz de Chapecó

Furnas (40%)

RS/SC

855.0

432.0

947,297

925,442

Oct-10

Nov-36

1,266.00

141.00

-

Serra do Facão Energia S.A.

HPU Serra do Facão

Furnas (49,5%)

GO

212.6

182.4

65,079

35,006

Jul-10

Nov-36

353.00

118.00

186.00

Madeira Energia S.A.

HPU Santo Antônio

Furnas (39%)

RO

3,568.0

2,424.2

4,928,552

4,870,876

Mar-12

Jun-43

4,429.00

137.00

2,136.00

Teles Pires Participações S.A.

HPU Três Irmãos

Furnas (49,9%)

SP

1,819.8

930.7

3,384,426

3,505,289

Nov-15

Jun-46

1,586.00

87.00

1,030.00

Tijoá Participações e Investimentos S.A.

HPU Teles Pires

Furnas (24,5%)
Eletrosul (24,72%)

PA/MT

807.5

217.5

900,000

-

Oct-14

Sep-44

-

-

-

Eólica Livramento S.A. *

WPP of Cerro Chato IV, V, VI, Ibirapuitã e Trindade

Eletrosul (59%)

RS

25.2

11.7

15,428

21,302

Nov-13

Mar-47

-

207.88

11.70

Santa Vitória do Palmar S.A.

WPP Geribatu I a X

Eletrosul (49%)

RS

258.0

109.2

170,547

200,274

Feb-15

Apr-47

-

205.40

109.20

Eólica –Chuí Holding S.A.

WPP Chuí I a V, e Minuano I e II

Eletrosul (49%)

RS

144.0

59.6

88,214

105,928

May-15

Apr-47

-

206.10

59.60

Hermenegildo I S.A.**

WPP Verace 24 a 27

Eletrosul (99,99%)

RS

57.3

24.9

42,120

47,907

Nov-15

Jun-49

-

196.54

27.40

Hermenegildo II S.A.***

WPP Verace 28 a 31

Eletrosul (99,99%)

RS

57.3

25.3

36,761

44,953

Dec-15

Jun-49

-

194.95

26.60

Hermenegildo III S.A.***

WPP Verace 34 a 36

Eletrosul (99,99%)

RS

48.3

21.0

32,310

39,977

Dec-15

Jun-49

-

194.43

22.20

Chuí IX S.A.***

WPP Chuí 09

Eletrosul (99,99%)

RS

17.9

7.4

12,216

14,135

Oct-15

May-49

-

194.61

7.80

(1) The plant is out of operation since 07.04.2014. The Data Collection System - SCD has been disabled.

                  

(2) Amapari is inoperative since 07/04/2014, not having generation and trading data.

                    

(3) 11 generation units operating totalling 3,288.60 MW in commercial operation.

                   

(4) It includes 20% FCE and 10% Self-producer

                        

(5) Due to the plant motorization and current injunction limiting the energy revenues to a percentage of the physical guarantee of commercial operations, it is not possible to calculate in advance the tradable energy. Nowadays, currently insatalled capacity in commercial operation is 3,288.6 MW.

(6) The first turbine began operating in Sep/2013 with 75MW of installed capacity. In Dec/2016 the company totaled 50 machines in operation, resulting in an installed capacity of 3,750 MW (all of them operating). Increased physical guarantee of HPU Jirau due to revision of the hydraulic loss, as MME Ordinance No. 337 of 11.10.2015.

(7) The participation of SPEs V. Santa Joana IX, X, XI, XII, XIII, XIV and XV Energias Renováveis SA were merged into the Chapada do Piaui I Holding S.A.

            

(8) The participation of SPEs V. Santa Joana IX, X, XI, XII, XIII, XIV and XV Energias Renováveis SA were merged into the Chapada do Piaui I Holding S.A.

            

(9) The participation of SPEs WPP Caiçara I S.A., WPP Caiçara II S.A., WPP Junco I S.A. and WPP Junco II S.A. were merged into the company Vamcruz I Participações AS

          

(10) The shares of the SPEs were merged into the company Serra das Vacas Holding S.A.

                    

* In commercial operation 25.2 MW corresponding to Ibirapuitã park (which energy assured is of 11,7 MW). The suspension of the operation of the other parks is under discussing at court due to the accident occurred in Dec 2014.

** In April 2017, Energy trading agreement in a regulated environment (CCEAR) changed into Mechanism of compensation of surpluses and deficits (MCSD). From marketable energy, nearly 78% is hired by Eletrosul via Power Purchase Agreement - PPA, at average market price informed.

*** In April 2017, Energy trading agreement in a regulated environment (CCEAR) changed into Mechanism of compensation of surpluses and deficits (MCSD). From marketable energy, nearly 81% is hired by Eletrosul via Power Purchase Agreement - PPA, at average market price informed.

 

60

 

 

DFR - Investor Relations Superintendence

Marketletter - Annex III - 2Q17

Operating Information of the Subsidiaries

VII.1.1.2 Energy Sold

              

SPE

Eletrobras Companies (%)

Buyer

Sell Type

1Q17

2Q17

R$ million

MWh

R$ million

MWh

EAPSA - Energia Águas Da Pedra S.A.

Eletronorte (24,5%)
Chesf (24,5%)

Eletrobras System

A

-

-

-

-

B

-

-

-

-

Others

A

-

-

-

-

B

66.87

329,029

63.87

310,485

Amapari Energia S.A. (1)

Eletronorte (49%)

Eletrobras System

A

-

-

-

-

B

-

-

-

-

Others

A

-

-

-

-

B

-

-

-

-

Brasventos Miassaba 3 Geradora de Energia S.A

Eletronorte (24,5%)
Furnas (24,5%)

Eletrobras System

A

8.28

35,017

7.13

30,154

B

-

-

-

-

Others

A

-

-

-

-

B

-

-

-

-

Brasventos Eolo Geradora de Energia S.A.

Eletronorte (24,5%)
Furnas (24,5%)

Eletrobras System

A

8.36

35,204

5.91

24,866

B

-

-

-

-

Others

A

-

-

-

-

B

-

-

-

-

Rei dos Ventos 3 Geradora de Energia S.A.

Eletronorte (24,5%)
Furnas (24,5%)

Eletrobras System

A

7.26

30,487

6.50

27,315

B

-

-

-

-

Others

A

-

-

-

-

B

-

-

-

-

ESBR Participações S.A.

Chesf (20%)
Eletrosul (20%)

Eletrobras System

A

45.14

408,735

35.84

322,685

B

83.42

446,870

91.87

495,555

Others

A

376.42

3,425,086

263.37

2,361,075

B

151.48

837,821

317.02

1,574,740

Norte Energia S.A.

Chesf (15%)
Eletronorte (19,98%)
Eletrobras Holding (15%)

Eletrobras System

A

-

-

-

-

B

-

-

-

-

Others

A

507.66

4,171,216

649.07

5,232,207

B

-

-

-

-

Pedra Branca S.A.

Chesf (49%)

Eletrobras System

A

3.07

12,275

3.07

15,037

B

-

-

-

-

Others

A

2.54

10,177

2.37

11,608

B

-

-

-

-

São Pedro do Lago S.A.

Chesf (49%)

Eletrobras System

A

3.32

11,714

3.32

16,269

B

-

-

-

-

Others

A

2.52

8,889

2.56

12,559

B

-

-

-

-

Sete Gameleiras S.A.

Chesf (49%)

Eletrobras System

A

3.14

7,818

3.14

15,407

B

-

-

-

-

Others

A

5.43

13,523

2.42

11,893

B

-

-

-

-

Baraúnas I Energética S.A. (3)

Chesf (49%)

Eletrobras System

A

3.93

23,189

-

-

B

-

-

-

-

Others

A

-

-

3.93

26,645

B

-

-

-

-

Mussambê Energética S.A. (3)

Chesf (49%)

Eletrobras System

A

3.68

21,295

-

-

B

-

-

-

-

Others

A

-

-

3.68

24,898

B

-

-

-

-

Morro Branco I Energética S.A. (3)

Chesf (49%)

Eletrobras System

A

4.03

22,083

-

-

B

-

-

-

-

Others

A

-

-

4.03

27,300

B

-

-

-

-

Banda de Couro Energética S.A.

Chesf (1,7%)

Eletrobras System

A

3.51

19,356

1.90

12,356

B

-

-

-

-

Others

A

-

-

1.98

12,858

B

-

-

-

-

Baraúnas II Energética S.A.

Chesf (1,5%)

Eletrobras System

A

2.87

16,116

1.55

10,252

B

-

-

-

-

Others

A

-

-

1.62

10,681

B

-

-

-

-

V. de Santa Joana IX Energia Renováveis S.A. (2)

Chesf (49%)

Eletrobras System

A

3.96

28,525

3.96

28,829

B

-

-

-

-

Others

A

-

-

-

-

B

-

-

-

-

V. de Santa Joana X Energia Renováveis S.A. (2)

Chesf (49%)

Eletrobras System

A

4.16

30,029

4.16

29,702

B

-

-

-

-

Others

A

-

-

-

-

B

-

-

-

-

V. de Santa Joana XI Energia Renováveis S.A. (2)

Chesf (49%)

Eletrobras System

A

4.00

30,470

4.00

30,794

B

-

-

-

-

Others

A

-

-

-

-

B

-

-

-

-

V. de Santa Joana XII Energia Renováveis S.A. (2)

Chesf (49%)

Eletrobras System

A

4.68

33,063

4.68

33,415

B

-

-

-

-

Others

A

-

-

-

-

B

-

-

-

-

V. de Santa Joana XIII Energia Renováveis S.A. (2)

Chesf (49%)

Eletrobras System

A

4.08

28,957

4.08

29,266

B

-

-

-

-

Others

A

-

-

-

-

B

-

-

-

-

V. de Santa Joana XV Energia Renováveis S.A. (2)

Chesf (49%)

Eletrobras System

A

4.59

32,415

4.59

32,760

B

-

-

-

-

Others

A

-

-

-

-

B

-

-

-

-

V. de Santa Joana XVI Energia Renováveis S.A. (2)

Chesf (49%)

Eletrobras System

A

4.68

33,063

4.68

33,415

B

-

-

-

-

Others

A

-

-

-

-

B

-

-

-

-

V. de Santa Joana I Energia Renováveis S.A. (2)

Chesf (49%)

Eletrobras System

A

5.24

31,767

5.42

32,105

B

-

-

-

-

Others

A

-

-

-

-

B

-

-

-

-

V. de Santa Joana III Energia Renováveis S.A. (2)

Chesf (49%)

Eletrobras System

A

4.65

28,957

4.81

29,266

B

-

-

-

-

Others

A

-

-

-

-

B

-

-

-

-

V. de Santa Joana IV Energia Renováveis S.A. (2)

Chesf (49%)

Eletrobras System

A

5.13

30,686

5.30

31,013

B

-

-

-

-

Others

A

-

-

-

-

B

-

-

-

-

V. de Santa Joana V Energia Renováveis S.A. (2)

Chesf (49%)

Eletrobras System

A

5.09

30,470

5.26

30,794

B

-

-

-

-

Others

A

-

-

-

-

B

-

-

-

-

V. de Santa Joana VII Energia Renováveis S.A. (2)

Chesf (49%)

Eletrobras System

A

5.35

31,983

5.52

32,323

B

-

-

-

-

Others

A

-

-

-

-

B

-

-

-

-

V. de Santo Augusto IV Energia Renováveis S.A. (2)

Chesf (49%)

Eletrobras System

A

5.51

33,279

5.69

33,634

B

-

-

-

-

Others

A

-

-

-

-

B

-

-

-

-

U.E.E. Caiçara I S.A.

Chesf (49%)

Eletrobras System

A

-

-

-

-

B

-

-

-

-

Others

A

4.55

29,174

4.60

29,484

B

0.56

2,361

0.40

972

U.E.E. Caiçara II S.A.

Chesf (49%)

Eletrobras System

A

-

-

-

-

B

-

-

-

-

Others

A

3.13

20,104

3.17

20,318

B

0.00

5

-

-

U.E.E. Junco I S.A.

Chesf (49%)

Eletrobras System

A

-

-

-

-

B

-

-

-

-

Others

A

4.11

26,152

4.15

26,431

B

1.14

3,755

0.20

479

U.E.E. Junco II S.A

Chesf (49%)

Eletrobras System

A

-

-

-

-

B

-

-

-

-

Others

A

3.85

24,638

3.89

24,900

B

0.95

3,665

0.51

1,245

Eólica Serra das Vacas I S.A.

Chesf (49%)

Eletrobras System

A

-

-

-

-

B

-

-

-

-

Others

A

4.11

26,364

4.15

26,645

B

-

-

-

-

Eólica Serra das Vacas II S.A.

Chesf (49%)

Eletrobras System

A

-

-

-

-

B

-

-

-

-

Others

A

3.33

21,394

3.36

21,622

B

0.18

1,020

0.27

828

Eólica Serra das Vacas III S.A.

Chesf (49%)

Eletrobras System

A

-

-

-

-

B

-

-

-

-

Others

A

3.71

23,771

3.75

24,024

B

0.05

280

0.05

145

Eólica Serra das Vacas IV S.A.

Chesf (49%)

Eletrobras System

A

-

-

-

-

B

-

-

-

-

Others

A

3.54

22,691

3.58

22,932

B

0.13

740

0.20

617

Enerpeixe S.A.

Furnas (40%)

Eletrobras System

A

-

-

-

-

B

-

-

-

-

Others

A

1.43

9,142

0.81

5,204

B

23.25

138,484

23.53

146,525

Baguari Geração de Energia S.A.

Furnas (15%)

Eletrobras System

A

0.33

1,511

-

-

B

-

-

-

-

Others

A

17.69

82,898

17.37

80,426

B

-

-

-

-

Retiro Baixo Energética S.A.

Furnas (49%)

Eletrobras System

A

-

-

-

-

B

-

-

-

-

Others

A

16.90

79,466

16.45

76,167

B

0.50

2,161

0.50

2,161

Foz de Chapecó Energia S.A.

Furnas (40%)

Eletrobras System

A

-

-

-

-

B

-

-

-

-

Others

A

132.28

581,316

125.47

543,922

B

88.60

373,248

89.58

377,395

Serra do Facão Energia S.A.

Furnas (49,5%)

Eletrobras System

A

8.96

39,037

8.75

26,599

B

-

-

-

-

Others

A

51.72

337,733

50.52

230,125

B

25.62

110,211

31.59

135,906

Madeira Energia S.A.

Furnas (39%)

Eletrobras System

A

16.87

122,619

'

104,891

B

-

-

-

-

Others

A

495.35

3,647,110

425.91

3,119,811

B

307.38

1,431,951

357.26

1,555,584

Tijoá Participações e Investimentos S.A.

Furnas (49,9%)

Eletrobras System

A

-

N/A

N/A

B

-

-

N/A

N/A

Others

A

-

-

N/A

N/A

B

-

-

N/A

N/A

Teles Pires Participações S.A.

Furnas (24,5%)
Eletrosul (24,72%)

Eletrobras System

A

12.18

203,332

8.71

142,227

B

32.42

172,847

75.29

388,718

Others

A

128.56

1,447,358

92.04

1,012,400

B

33.74

179,902

78.36

404,584

Eólica Livramento S.A.

Eletrosul (59%)

Eletrobras System

A

0.23

1,668

-

-

B

-

-

-

-

Others

A

1.91

13,760

7.13

24,720

B

-

-

-

-

Santa Vitória do Palmar S.A.

Eletrosul (49%)

Eletrobras System

A

2.61

18,440

-

-

B

-

-

-

-

Others

A

21.55

152,108

66.81

231,360

B

-

-

-

-

Eólica –Chuí Holding S.A.

Eletrosul (49%)

Eletrobras System

A

1.41

9,538

-

-

B

-

-

-

-

Others

A

11.64

78,677

36.26

125,830

B

-

-

-

-

Hermenegildo I S.A.

Eletrosul (99,99%)

Eletrobras System

A

-

-

-

-

B

2.45

15,336

9.32

47,907

Others

A

6.64

41,904

-

-

B

-

-

-

-

Hermenegildo II S.A.

Eletrosul (99,99%)

Eletrobras System

A

-

-

-

-

B

2.65

16,632

8.75

44,953

Others

A

6.44

40,824

-

-

B

-

-

-

-

Hermenegildo III S.A.

Eletrosul (99,99%)

Eletrobras System

A

-

-

-

-

B

2.27

14,256

7.78

39,977

Others

A

5.31

33,696

-

-

B

-

-

-

-

Chuí IX S.A.

Eletrosul (99,99%)

Eletrobras System

A

-

-

-

-

B

0.79

4,968

2.75

14,135

Others

A

1.87

11,880

-

-

B

-

-

-

-

(1) The plant is out of operation since 07.04.2014. The Data Collection System - SCD has been disabled. About SPC AMAPARI we reiterate that there was no change from last quarter. Source: ENGO/Eletronorte.

(2) The SPC informs that there is no energy purchased for resale. There is no need to replace non-produced energy. If below 90% of the energy sold at the end of the 1-year cycle, there is a penalty.

(3) The SPC did not inform "Eletrobras System" and "Others" amounts. The Commercialization Chamber of Electric Energy (CCEE) requested this information and is still waiting for feedback.

 

61

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex III - 2Q17

Operating Information of the Subsidiaries

VII.1.1.3 Average Rate – R$/MWh

    

SPE

Eletrobras Companies (%)

1Q17

2Q17

EAPSA - Energia Águas Da Pedra S.A.

Eletronorte (24,5%)
Chesf (24,5%)

203.21

206.09

Amapari Energia S.A.

Eletronorte (49%)

-

-

Brasventos Miassaba 3 Geradora de Energia S.A

Eletronorte (24,5%)
Furnas (24,5%)

236.43

236.43

Brasventos Eolo Geradora de Energia S.A.

Eletronorte (24,5%)
Furnas (24,5%)

237.52

237.52

Rei dos Ventos 3 Geradora de Energia S.A.

Eletronorte (24,5%)
Furnas (24,5%)

237.99

237.99

ESBR Participações S.A.

Chesf (20%)
Eletrosul (20%)

128.25

148.94

Norte Energia S.A.

Chesf (15%)
Eletronorte (19,98%)
Eletrobras Holding (15%)

121.70

124.05

Pedra Branca S.A.

Chesf (49%)

203.32

203.32

São Pedro do Lago S.A.

Chesf (49%)

203.32

203.32

Sete Gameleiras S.A.

Chesf (49%)

203.32

203.32

Baraúnas I Energética S.A.

Chesf (49%)

147.21

147.21

Mussambê Energética S.A.

Chesf (49%)

147.21

147.21

Morro Branco I Energética S.A.

Chesf (49%)

147.21

147.21

Banda de Couro Energética S.A.

Chesf (1,7%)

153.86

153.86

Baraúnas II Energética S.A.

Chesf (1,5%)

151.57

151.57

V. de Santa Joana IX Energia Renováveis S.A.

Chesf (49%)

139.79

139.79

V. de Santa Joana X Energia Renováveis S.A.

Chesf (49%)

139.79

139.79

V. de Santa Joana XI Energia Renováveis S.A.

Chesf (49%)

139.79

139.79

V. de Santa Joana XII Energia Renováveis S.A.

Chesf (49%)

139.79

139.79

V. de Santa Joana XIII Energia Renováveis S.A.

Chesf (49%)

139.79

139.79

V. de Santa Joana XV Energia Renováveis S.A.

Chesf (49%)

139.79

139.79

V. de Santa Joana XVI Energia Renováveis S.A.

Chesf (49%)

139.79

139.79

V. de Santa Joana I Energia Renováveis S.A.

Chesf (49%)

157.11

167.45

V. de Santa Joana III Energia Renováveis S.A.

Chesf (49%)

156.67

166.97

V. de Santa Joana IV Energia Renováveis S.A.

Chesf (49%)

156.89

167.21

V. de Santa Joana V Energia Renováveis S.A.

Chesf (49%)

156.85

167.17

V. de Santa Joana VII Energia Renováveis S.A.

Chesf (49%)

156.88

167.20

V. de Santo Augusto IV Energia Renováveis S.A.

Chesf (49%)

155.25

165.46

WPP. Caiçara I S.A.

Chesf (49%)

155.89

155.89

WPP. Caiçara II S.A.

Chesf (49%)

155.84

155.84

WPP. Junco I S.A.

Chesf (49%)

157.01

157.01

WPP. Junco II S.A

Chesf (49%)

156.20

156.20

Eólica Serra das Vacas I S.A.

Chesf (49%)

155.88

156.31

Eólica Serra das Vacas II S.A.

Chesf (49%)

156.28

161.92

Eólica Serra das Vacas III S.A.

Chesf (49%)

156.13

157.17

Eólica Serra das Vacas IV S.A.

Chesf (49%)

156.56

160.40

Enerpeixe S.A.

Furnas (40%)

156.60

134.44

Baguari Geração de Energia S.A.

Furnas (15%)

213.42

138.19

Retiro Baixo Energética S.A.

Furnas (49%)

212.96

55.27

Foz de Chapecó Energia S.A.

Furnas (40%)

231.39

211.07

Serra do Facão Energia S.A.

Furnas (49,5%)

229.04

124.84

Madeira Energia S.A.

Furnas (39%)

160.00

-

Tijoá Participações e Investimentos S.A.

Furnas (49,9%)

-

N/A

Teles Pires Participações S.A.

Furnas (24,5%)
Eletrosul (24,72%)

98.06

73.10

Eólica Livramento S.A.

Eletrosul (59%)

138.83

281.15

Santa Vitória do Palmar S.A.

Eletrosul (49%)

141.68

281.01

Eólica –Chuí Holding S.A.

Eletrosul (49%)

147.90

282.19

Hermenegildo I S.A.

Eletrosul (99,99%)

158.71

196.54

Hermenegildo II S.A.

Eletrosul (99,99%)

158.19

194.95

Hermenegildo III S.A.

Eletrosul (99,99%)

158.08

194.43

Chuí IX S.A.

Eletrosul (99,99%)

158.11

194.61

 

62

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex III - 2Q17

Operating Information of the Subsidiaries

VII.1.2 Transmission

                
                 

VII.1.2.1 Operational Asset

               
                 

VII.1.2.1.1 Transmission Lines

                

SPE

From - To

Eletrobras Companies (%)

Extension (km)

Tension (kV)

Beginning of Operation

End of Concession

AAR on 06.30.17 (R$ Million)

Readjustment Index

AETE - Amazônia Eletronorte Transmissora de Energia S.A.

Coxipó-Cuiabá-Rondonópolis (MT), SE Portioning Cuiabá

Eletronorte (49%)

193

230

Aug-05

Feb-34

3.16

2.14%

INTESA - Integração Transmissora de Energia S.A.

Colinas-Miracema-Gurupi-Peixe Nova-Serra da Mesa 2 (TO / GO)

Eletronorte (37%)
Chesf (12%)

695

500

May-08

Apr-36

-

9.32%

BRASNORTE Transmissora de Energia S.A.

Jauru - Juba – C2 (MT) e Maggi - Nova Mutum (MT), SE Juba e SE Maggi - 230/138 kV

Eletronorte (49,71%)

402

230

Sep-09

Mar-38

10.19

8.86%

Transmissora Matogrossense de Energia S.A. – TME

LT Jauru / Cuiabá, em 230 kV, Mato Grosso

Eletronorte (49%)

348

500

Nov-11

Nov-39

43.57

3.60%

Manaus Transmissora de Energia S.A.

Oriximiná - Silves - Lechuga (AM), SE Silves (ex-Itacoatiara) e SE Lechuga (ex-Cariri)

Eletronorte (30%)
Chesf (19,5%)

559

500

Mar-13

Oct-38

172.83

3.60%

Norte Brasil Transmissora de Energia S.A.

Coletora Porto Velho (RO) - Araraquara (SPE)

Eletronorte (49%)

2411.9

600

nov/14

Feb-39

288.83

3.60%

Sistema de Transmissão do Nordeste S.A.

Teresina II/PI-Sobral III/CE;
Teresina II/PI-Fortaleza II/CE;
Sobral III/CE-Fortaleza II/CE

Chesf (49%)

546

500

Jan-06

Feb-34

177.33

11.09%

Interligação Elétrica do Madeira S.A.

LT Coletora Porto Velho/ Araraquara II, CS

Chesf (24,5%)
Furnas (24,5%)

2,375

600

Aug-13

Feb-39

292.07

9.32%

Interligação Elétrica Garanhuns S.A.

L.Gonzaga/Garanhuns II;
Garanhuns II/Campina Grande III;
Garanhuns II/Pau Ferro;
Garanhuns II/Angelim I

Chesf (49%)

224
190
239
13

500
500
500
230

nov/15
nov/15
dez/15
mar/16

Dec-41

96.53

9.32%

Extremoz Transmissora do Nordeste –ETN S.A.

LT Ceará Mirim/João Câmara II
LT Ceará Mirim/ Extremoz II
LT Ceará Mirim/ Campina III, 500 kV
LT Campina Grande III/Campina Grande II, 230 kV

Chesf (100%)

64
19
192
10

500
230
500
230

out/14
out/14
mai/15
mai/15

Oct-41

65.53

9.32%

Baguari Energia S.A.

HPU Baguari - SE Baguari

Furnas (15%)

0.8

230

Feb-10

Aug-41

0

(1)

SS Baguari - Mesquita – Governador Valadares

2.5

230

Apr-10

Aug-41

0

(1)

SS Baguari – Mesquita

69

230

Apr-10

Aug-41

0

(1)

SS Baguari - Gov. Valadares

26

230

Apr-10

Aug-41

0

(1)

Centroeste de Minas

Furnas – Pimenta II

Furnas (49%)

62.7

345

Mar-10

Mar-35

-

IGPM

Chapecoense Geração S.A.

SS Foz do Chapecó – Gurita

Furnas (40%)

72.6

230

Mar-11

Nov-36

-

(1)

SS Foz do Chapecó – SE Xanxerê

77.6

230

Mar-11

Nov-36

-

(1)

HPU Foz do Chapecó – SE de Foz do Chapecó

1

230

Mar-11

Nov-36

-

(1)

Enerpeixe S.A.

Peixe Angical – Peixe 2

Furnas (40%)

17

500

Apr-06

Nov-36

-

(1)

Goiás Transmissão S.A.

Rio Verde Norte – Trindade

Furnas (49%)

193

500

Dec-13

Jul-40

-

IPCA

Trindade – Xavantes

37

230

Dec-13

Jul-40

Trindade – Carajás

29

230

Oct-13

Jul-40

MGE Transmissão S.A.

Mesquita - Viana 2

Furnas (49%)

248

500

Jun-14

Jul-40

-

IPCA

Viana 2 – Viana

10

345

Jun-14

Jul-40

Retiro Baixo Energética S.A.

HPU Retiro Baixo – SE Curvelo

Furnas (49%)

45

138

Oct-10

Aug-41

-

(1)

Serra do Facão Energia S.A.

HPU Serra do Facão – SE Celg de Catalão

Furnas (49,5%)

32

138

Oct-10

Nov-36

-

(1)

Transenergia Renovável S.A.

Barra dos Coqueiros – Quirinópolis

Furnas (49%)

51

230

Apr-11

Apr-39

-

IPCA

Quirinópolis - UTE Quirinópolis

34

138

May-11

Jun-25

Quirinópolis - UTE Boavista

17

138

May-11

Jun-25

Chapadão – Jataí

138

230

Dec-12

Apr-39

Jataí – Mineiros

61

138

Dec-12

Jun-25

Jataí - UTE Jataí

52

138

Dec-12

Jun-25

Jataí - UTE Água Emendada

33

138

Dec-12

Jun-25

Mineiros - Morro Vermelho

47

138

Dec-12

Jun-25

Morro Vermelho - UTE Morro Vermelho

31

138

Dec-12

Jun-25

Palmeiras – Edéia

59

230

May-13

Apr-39

Edéia - UTE Tropical Bionenergia I

49

138

mai/13

Jun-25

Transirapé

Irapé – Araçuaí

Furnas (24,5%)

65

230

May-07

Mar-35

-

IGPM

Transleste

Montes Claros – Irapé

Furnas (24,5%)

138

345

Dec-06

Feb-34

-

IGPM

Transudeste

Itutinga – Juiz de Fora

Furnas (25%)

140

345

Feb-07

Mar-35

-

IGPM

Transenergia Goiás S.A.

Niquelândia - Barro Alto

Furnas (99%)

88

230

May-16

Nov-39

-

IPCA

Energia Olímpica S.A.

Barra da Tijuca – SE Olímpica;

Furnas (49,9%)

10.8

138

May-15

n/a

(2)

0.00%

Gardênia – SE Olímpica

2.9

138

May-15

n/a

-

0.00%

Paranaíba Transmissora de Energia S.A.

Luziânia - Pirapora II

Furnas (24,5%)

350

500

May-16

May-43

-

IPCA

Rio das Éguas - Luziânia

373

500

Jul-16

May-43

Barreiras II - Rio das Éguas

244

500

Jan-17

May-43

Lago Azul Transmissora S.A.

Barro Alto - Itapaci

Furnas (49,9%)

69

230

Sep-16

May-44

-

0.00%

Vale do São Bartolomeu Transmissora de Energia S.A.

Samambaia - Brasília Sul

Furnas (39%)

14

345

May-16

Oct-43

-

IPCA

Triângulo Mineiro Transmissora S.A.

Marimbondo II - Assis

Furnas (49%)

13.5

230

Dec-16

Aug-43

-

IPCA

Etau

Campos Novos (SC) – Barra Grande (SC) – Lagoa Vermelha (RS) – Santa Marta (RS)

Eletrosul (27,42%)

188

230

Jul-05

Dec-32

23.39

IGPM

Uirapuru

Ivaiporã (PR) – Londrina (PR))

Eletrosul (75%)

120

525

Jul-06

Mar-35

30.59

IGPM

Transmissora Sul Brasileira de Energia – TSBE

Salto Santiago – Itá

Eletrosul (80%)

187

525

Feb-14

May-42

16.16

IPCA

Itá – Nova Santa Rita

307

525

Aug-14

Jan-00

25.94

Nova Santa Rita – Camaquã

126

230

Dec-14

Jan-00

6.30

Camaquã - Povo Novo - Quinta

168

230

Dec-14

Jan-00

7.34

Costa Oeste

Cascavel Oeste – Umuarama, CS

Eletrosul (49%)

151.5

230

Sep-14

Jan-42

8.69

IPCA

 

Povo Novo – Marmeleiro, CS

Eletrosul (51%)

152

525

Dec-14

Aug-42

16.79

IPCA

Transmissora Sul Litorânea de Energia - TSLE

Nova santa Rita – Povo Novo, CS

268

525

Mar-15

Jan-00

29.01

 

Marmeleiro – Santa Vitória do Palmar

48

525

Dec-14

Jan-00

5.37

Marumbi Transmissora de Energia S.A.

Curitiba / Curitiba Leste (PR)

Eletrosul (20%)

29.04

525

Jun-15

May-42

5.61

IPCA

Fronteira Oeste Transmissora de Energia S.A. (Fote)

Portioning LT Alegrete 1 - Santa Maria 1

Eletrosul (51%)

1.95

138

May-16

Jan-44

1.08

IPCA

(1) There is no AAR because facilities are of limited interest to the generating plant.

              

(2) The participation of Furnas in this project is only technical. Furnas is not taking part of the share capital of the company and, therefore, not entitled to AAR.

     

 

63

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex III - 2Q17

Operating Information of the Subsidiaries

VII.1.2.1.2 Substations

              

SPE

Substation

Eletrobras Companies (%)

Transformation Capacity - MVA

Beginning of Operation

End of Concession

AAR on 06.30.17 (R$ million)

Readjustment Index

AETE - Amazônia Eletronorte Transmissora de Energia S.A.

SS Portioning Cuiabá

Eletronorte (49%)

n/a

Aug-05

Feb-34

0.73

2%

BRASNORTE Transmissora de Energia S.A.

SS Juba
SS Maggi - 230/138 kV

Eletronorte (49,71%)

300
100

Sep-09

Mar-38

3.46

9%

Manaus Transmissora de Energia S.A.

SS Silves (ex-Itacoatiara)
SS Lechuga (ex-Cariri)

Eletronorte (30%)
Chesf (19,5%)

150
1800

Mar-13

Oct-38

-

9%

INTESA - Integração Transmissora de Energia S.A.

SS Peixe 2
SS Serra da Mesa 2

Eletronorte (37%)
Chesf (12%)

-

May-08

Apr-36

-

9%

Transmissora Matogrossense de Energia S.A. – TME

SS Jauru 500/230 kV

Eletronorte (49%)

750

Nov-11

Nov-39

6.51

4%

Interligação Elétrica do Madeira S.A.

Retifier Station CA/CC from 500 kV to +/- 600 kV;
Inverter Station CC/CA from +/- 600 kV to 500 kV.

Chesf (24,5%)
Furnas (24,5%)

3150
2950

May-14

Feb-39

252.42

9.32%

TDG – Transmissora Delmiro Gouveia S.A.

SS – Pecém II, of 500/230 kV;
SS – Aquiraz, of 230/69 kV

Chesf (49%)

3600
450

Oct-13

Jul-40

26.90

9.32%

Interligação Elétrica Garanhuns S.A.

SS – Garanhuns, 500/230 kV
SS – Pau Ferro, 500/230 kV

Chesf (49%)

600
1500

nov/15
dez/15

Dec-41

(*)

(*)

Extremoz Transmissora do Nordeste - ETN S.A.

SS – João Câmara II, 500/138 kV
SS – Ceará Mirim, 500/230 kV
SS – Campina Grande III, 500/230 kV

Chesf (100%)

1.800
900
1.200

out/14
out/14
mai/15

Oct-41

(*)

(*)

Luziânia Niquelândia Transmissora S.A.

SS Luziânia

Furnas (49%)

225

Jun-14

May-42

-

IPCA

SS Niquelândia

30

Aug-15

May-42

Energia Olímpica S.A.

SS Olímpica 138/13,8 kV

Furnas (49,9%)

120

May-15

n/a

(6)

N/A

Caldas Novas Transmissão S.A. (3)

Extansion of SS Corfumbá

Furnas (49%)

150

Jul-13

Jun-41

-

IPCA

Baguari Energia S.A.

SS of Baguari Plant

Furnas (15%)

155.6

Aug-06

Aug-41

-

N/A

Chapecoense Geração S.A.

SS of Foz do Chapecó Plant

Furnas (40%)

978

Nov-01

Nov-36

-

N/A

Enerpeixe S.A.

SS of Peixe Angical Plant

Furnas (40%)

525

Nov-01

Nov-36

-

N/A

Goiás Transmissão S.A.

SS Trindade

Furnas (49%)

1200

Nov-13

Jul-40

-

(3)

Madeira Energia S.A.

SS of Santo Antônio Plant

Furnas (39%)

3630

Aug-07

Jun-43

-

N/A

MGE Transmissão S.A.

Viana 2

Furnas (49%)

900

Aug-14

Jul-40

-

(3)

Retiro Baixo Energética S.A.

SS of Retiro Baixo Plant

Furnas (49%)

100

Aug-06

Aug-41

-

N/A

Serra do Facão Energia S.A.

SS of Serra do Facão Plant

Furnas (49,5%)

236.4

Nov-01

Nov-36

-

N/A

Transenergia Renovável S.A

Edéia

Furnas (49%)

150

Feb-12

Jun-25

-

(3)

Jataí

450

Dec-12

Jun-25

-

(3)

Mineiros

0

Dec-12

Jun-25

-

(3)

Morro Vermelho

0

Dec-12

Jun-25

-

(3)

Quirinópolis

225

Apr-11

Jun-25

-

(3)

Transenergia São Paulo S.A

Itatiba

Furnas (49%)

800

Aug-12

Nov-39

-

IPCA

Interligação Elétrica do Madeira S.A.

Retifier Station CA/CC from 500 kV to +/- 600 kV;

Furnas (24,5%)

3832

May-14

Feb-39

-

IPCA

Inverter Station CC/CA from +/- 600 kV to 500 kV.

3632

May-14

Feb-39

Triângulo Mineiro Transmissora S.A.

SS Marimbondo II

Furnas (49%)

(5)

Dec-16

Aug-43

-

(3)

SS Assis

(6)

Dec-16

Aug-43

Etau (7)

Lagoa Vermelha 2 230/138KV;
Barra Grande 230/138 KV; Santa Marta 230 KV - Entrada de Linha; Extension Lagoa Vermelha 2 230/138KV

Eletrosul (27,42%)

150
-
-
150

abr/05
jul/05
jul/05
out/16

Dec-32

21.94

IGPM

Transmissora Sul Brasileira de Energia – TSBE

Extension SS 525 KV Salto Santiago;
Extension SS 525 kV Itá
Extension SS 525/230kV; Nova Santa Rita;
Camaquã 3 230/69Kv ;
Extension SS 230 kV Quinta

Eletrosul (80%)

-
-
-

166
-

fev/14
ago/14
ago/14
dez/14
dez/14

May-42

12.44

IPCA

Costa Oeste (8)

Umuarama 230/138 kV

Eletrosul (49%)

300

Jul-14

Jan-42

4.06

IPCA

Transmissora Sul Litorânea de Energia - TSLE

Povo Novo525/230 kV;
Santa Vitória do Palmar 525/138 kV;
Marmeleiro 525 kV - Synchronous Compensator ±200 Mvar;
Extension SS Nova Santa Rita 525kV.

Eletrosul (51%)

672
75
-

-

dez/14
dez/14
dez/14

abr/15

Aug-42

52.84

IPCA

Marumbi Transmissora de Energia S.A.

Curitiba Leste - 525/230 KV

Eletrosul (20%)

672

Jun-15

May-42

14.63

IPCA

Fronteira Oeste Transmissora de Energia S.A. (Fote)

Extension of SS Santa Maria 3, 230/138 kV

Eletrosul (51%)

166

May-16

Jan-44

2.50

IPCA

(1) This venture consists of the expansion of SS Corumbá.

            

(2) Entries of lines and inscriptions associated with Campos Novos - Santa Marta TL located at the substations. The asset will be transferred to Eletrobras, as approved on April 19, 2017, at the 147th Extraordinary General Meeting (AGE).

(3) The amount of the active AAR of the Substations is informed together with that of the Transmission Line.

          

(4) 4 single-phase reators of 45,3 MVAr each.

              

(5) 7 single-phase reators of 45,3 MVAr each.

              

(6) The participation of Furnas in this project is only technical. Furnas is not taking part of the share capital of the company and, therefore, not entitled to AAR.

     

(7) Commercial operation by sharing with Copel (TL Caiuá).

            

(*) The substation AAR is being informed jointly with the TLs, according to the concession agreement.

              

 

64

 
 

DFR - Investor Relations Superintendence

Marketletter - Annex III - 2Q17

Operating Information of the Subsidiaries

VII.2 Financing and Loans – R$ million

                              

SPE

Eletrobras Companies (%)

BNDES - Brazilian Development Bank (a)

Others Creditors (b)

Total (a+b)

2018

2019

2020

2021

2022

2023

After 2023

2018

2019

2020

2021

2022

2023

After 2023

Belo Monte Transmissora de Energia S.A

Eletronorte (24,5%)

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

Furnas (24,5%)

Energética Águas da Pedra S.A.

Eletronorte (24,5%)

34.2

34.2

34.2

34.2

34.2

34.2

382.2

-

-

-

-

-

-

-

587.5

Chesf (24,5%)

Norte Brasil Transmissora de Energia S.A. (1)

Eletronorte (49%)

36.2

67.1

62.7

69.7

78.4

89.6

2,059.0

128.8

120.3

111.7

103.2

94.6

86.1

206.8

3,314.2

Manaus Transmissora de Energia S.A.

Eletronorte (30%)

39.0

31.9

31.9

31.9

31.9

31.9

84.7

39.4

35.0

35.0

35.0

35.0

35.0

231.1

728.6

Chesf (19,5%)

Transmissora Matogrossense de Energia S.A.

Eletronorte (49%)

23,290.7

20,155.6

17,018.8

13,876.8

10,734.9

7,593.0

4,449.9

30,897.5

27,858.4

24,818.8

21,780.2

18,741.1

15,702.0

12,662.6

249,580.4

Brasventos Eolo Geradora de Energia S.A.

Eletronorte (24,5%)

22.7

20.6

-

-

-

-

-

-

-

-

-

-

-

-

43.4

Furnas (24,5%)

Brasventos Miassaba 3 Geradora de Energia S.A.

Eletronorte (24,5%)

22.8

20.7

-

-

-

-

-

-

-

-

-

-

-

-

43.5

Furnas (24,5%)

Rei dos Ventos 3 Geradora de Energia S.A.

Eletronorte (24,5%)

24.0

21.7

-

-

-

-

-

-

-

-

-

-

-

-

45.7

Furnas (24,5%)

Norte Energia S.A.

Eletronorte (19,98%)

424.5

532.9

613.4

617.5

621.6

625.8

11,938.5

251.8

350.7

414.5

418.5

422.4

426.4

8,449.1

26,107.8

Chesf (15%)

Eletrobras Holding (15%)

Companhia Energética Sinop S.A.

Eletronorte (24,5%)

19.0

37.0

37.0

37.0

37.0

37.0

537.0

-

-

-

-

-

-

-

741.0

Chesf (24,5%)

Integração Transmissora de Energia S.A

Eletronorte (37%)

15.7

31.3

26.1

-

-

-

-

-

-

-

-

-

-

-

73.1

Chesf (12%)

Sistema de Transmissão Nordeste S.A. 

Chesf (49%)

-

-

-

-

-

-

-

11.0

22.5

23.7

18.3

13.5

14.4

7.0

110.3

Interligação Elétrica do Madeira S.A.

Chesf (24,5%)

119.4

119.4

119.4

119.4

115.7

486.1

1,483.1

41.0

58.7

71.9

76.4

80.8

300.3

780.1

3,971.7

Furnas (24,5%)

Interligação Elétrica Garanhuns S.A.

Chesf (49%)

32.5

32.5

32.5

32.5

32.5

27.8

91.2

-

-

-

-

-

-

-

281.7

Transmissora Delmiro Gouveia S.A.

Chesf (49%)

-

-

-

-

-

-

-

4.0

4.0

5.0

6.0

7.0

8.0

128.0

162.0

ESBR Participações S.A.

Chesf (20%)

122.6

171.8

185.0

201.8

201.4

200.9

4,332.9

120.4

163.6

177.0

193.9

194.3

194.8

4,433.4

11,977.4

Eletrosul (20%)

São Pedro do Lago S.A.

Chesf (49%)

3.0

5.2

5.2

5.2

5.2

5.2

30.2

-

-

-

-

-

-

-

59.1

Pedra Branca S.A.

Chesf (49%)

2.9

5.0

5.0

5.0

5.0

5.0

29.1

-

-

-

-

-

-

-

56.8

Sete Gameleiras S.A.

Chesf (49%)

2.9

5.0

5.0

5.0

5.0

5.0

81.1

-

-

-

-

-

-

-

109.0

Baraúnas I Energética S.A.

Chesf (49%)

3.7

4.9

4.9

4.9

4.9

4.9

39.9

-

-

-

-

-

-

-

68.2

Morro Branco I Energética S.A.

Chesf (49%)

5.2

5.2

5.2

5.2

5.2

5.2

108.8

-

-

-

-

-

-

-

139.7

Mussambê Energética S.A.

Chesf (49%)

2.6

4.5

4.5

4.5

4.5

4.5

41.9

-

-

-

-

-

-

-

67.1

Chapada do Piauí I Holding (2)

Chesf (49%)

21.2

23.2

25.3

27.6

30.0

32.6

405.0

-

-

0.4

0.2

0.1

5.0

78.1

648.8

Chapada do Piauí II Holding (3)

Chesf (49%)

36.9

37.4

37.9

38.3

38.8

39.3

309.8

-

-

-

-

-

-

-

538.4

Eólica Serra das Vacas I S.A.

Chesf (49%)

72.9

70.6

68.0

65.0

61.6

57.9

102.6

-

-

-

-

-

-

-

498.5

Eólica Serra das Vacas II S.A.

Chesf (49%)

66.0

63.9

61.5

58.8

55.8

52.4

92.8

-

-

-

-

-

-

-

451.1

Eólica Serra das Vacas III S.A.

Chesf (49%)

63.9

61.5

58.8

55.8

52.4

48.5

495.3

-

-

-

-

-

-

-

836.2

Eólica Serra das Vacas III S.A.

Chesf (49%)

66.0

63.9

61.5

58.8

55.8

52.4

92.8

-

-

-

-

-

-

-

451.1

Vamcruz I

Chesf (49%)

-

-

-

-

-

-

-

36.5

33.0

31.8

30.5

29.3

28.1

190.4

379.7

Baraúnas II Energética S.A.

Chesf (1,6%)

2.6

3.1

3.1

3.1

3.1

3.1

27.0

-

1.1

1.1

1.1

1.1

1.1

3.3

53.9

Banda de Couro Energética S.A.

Chesf (1,8%)

2.5

4.3

4.3

4.3

4.3

4.3

38.6

-

1.8

1.8

1.8

1.8

1.8

4.0

76.1

Foz do Chapecó

Furnas (40%)

89.0

88.4

75.8

75.8

75.8

75.8

303.1

45.7

45.4

40.2

40.2

40.2

40.2

160.8

1,196.3

Enerpeixe

Furnas (40%)

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

Santo Antônio

Furnas (39%)

495.7

669.9

669.9

669.9

669.9

669.9

6,574.3

495.7

867.8

1,033.7

1,184.9

1,466.1

1,466.1

12,140.1

29,073.9

Teles Pires

Furnas (24,5%)

136.1

180.0

203.4

203.4

203.4

203.4

2,280.5

-

-

-

-

-

-

-

3,409.9

Eletrosul (24,72%)

Centro Oeste de Minas

Furnas (49%)

2.9

2.8

3.0

3.0

3.0

1.0

-

-

-

-

-

-

-

-

15.6

Serra do Facão

Furnas (49,5%)

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

Retiro Baixo

Furnas (49%)

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

Goiás Transmissão

Furnas (49%)

6.7

6.7

6.7

6.7

6.7

6.7

53.7

-

-

-

-

-

-

-

94.0

MGE Transmissão

Furnas (49%)

4.6

9.2

9.2

9.2

9.2

9.2

19.2

-

-

-

-

-

-

-

70.0

Transenergia São Paulo

Furnas (49%)

3.2

4.3

4.3

4.3

4.3

4.3

15.0

-

-

-

-

-

-

-

39.4

Transenergia Renovável

Furnas (49%)

6.0

12.0

12.0

12.0

12.0

12.0

34.2

-

-

-

-

-

-

-

100.5

Triângulo Mineiro Transmissão S.A.

Furnas (49%)

-

-

-

-

-

-

-

20.4

21.4

22.4

22.4

22.4

22.4

13.1

144.3

Vale de São Bartolomeu Transmissão S.A.

Furnas (39%)

-

-

-

-

-

-

-

19.1

19.8

20.5

20.5

20.5

20.5

4.5

125.5

Mata de Santa Genebra S.A.

Furnas (49,9%)

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

Companhia Transirapé de Transmissão S.A.

Furnas (24,5%)

-

-

-

-

-

-

-

2.5

4.9

4.9

3.8

3.3

3.3

3.8

26.4

Companhia Transleste de Transmissão S.A.

Furnas (24,5%)

-

-

-

-

-

-

-

8.1

16.1

13.1

3.2

3.2

3.2

0.6

47.4

Companhia Transudeste de Transmissão S.A.

Furnas (25%)

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

São Manoel

Furnas (33,33%)

411.0

390.0

-

-

-

-

-

-

-

-

-

-

-

-

801.0

Paranaíba Transmissora de Energia S.A.

Furnas (24,5%)

-

-

-

-

-

-

-

20.5

41.0

41.0

41.0

41.0

41.0

320.8

546.0

Caldas Novas Transmissão S.A.

Furnas (49%)

5.0

4.0

-

-

-

-

-

-

-

-

-

-

-

-

9.0

Itaguaçu da Bahia Energias Renováveis S.A.

Furnas (49%)

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

Uirapuru Transmissora de Energia S.A.

Eletrosul (75%)

-

-

-

-

-

-

-

6.2

1.5

-

-

-

-

-

7.7

Transmissora Sul Litorânea de Energia S.A.  

Eletrosul (51%)

10.8

10.8

10.8

10.8

10.8

10.8

82.3

-

-

-

-

-

-

-

147.2

Transmissora Sul Brasileira de Energia S.A.  

Eletrosul (80%)

0.3

1.9

4.6

6.5

8.1

8.7

77.2

-

-

-

-

-

-

-

107.3

Santa Vitória do Palmar Holding S.A. 

Eletrosul (49%)

16.9

18.6

20.1

21.9

23.9

25.8

280.5

9.7

9.4

11.2

14.4

17.6

21.4

233.8

725.3

Marumbi Transmissora de Energia S.A.

Eletrosul (20%)

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

Livramento Holding S.A.

Eletrosul (59%)

3.3

3.3

3.3

3.3

3.3

3.3

21.7

-

-

-

-

-

-

-

41.7

Chuí Holding S.A.

Eletrosul (49%)

23.2

23.2

23.2

23.2

23.2

23.2

185.7

-

-

-

-

-

-

-

325.0

Costa Oeste Transmissora de Energia S.A.

Eletrosul (49%)

2.9

2.9

2.9

2.8

2.7

2.3

11.5

 

-

-

-

-

-

-

27.8

Fronteira Oeste Transmissora de Energia

Eletrosul (51%)

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

Chuí IX 

Eletrosul (99,99%)

2.1

2.1

2.1

2.1

2.1

2.1

17.1

0.9

0.9

0.9

0.9

0.9

0.9

7.5

42.4

Hermenegildo I

Eletrosul (99,99%)

7.2

7.2

7.2

7.2

7.2

7.2

59.4

3.2

3.2

3.2

3.2

3.2

3.2

25.9

147.3

Hermenegildo II

Eletrosul (99,99%)

7.2

7.2

7.2

7.2

7.2

7.2

59.3

3.2

3.2

3.2

3.2

3.2

3.2

25.9

147.3

Hermenegildo III

Eletrosul (99,99%)

6.1

6.1

6.1

6.1

6.1

6.1

50.6

2.7

2.7

2.7

2.7

2.7

2.7

22.1

125.6

Empresa de Transmissão do Alto Uruguai S.A.

Eletrosul (51%)

2.1

2.9

2.9

1.9

-

-

-

0.9

11.0

1.0

0.1

-

-

-

22.6

Paraíso Transmissora de Energia S.A.

Eletrosul (24,5%)

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

(1) Balance to be paid after 2017: R$ 6.00 million.

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

(2) The participation of SPEs V. Santa Joana IX, X, XI, XII, XIII, XIV and XV Renewable Energy SA were merged into the Chapada company Piaui I Holding S.A.

              

(3) The participation of SPEs V. Santa Joana I, III, IV, V, VII, Santo Augusto IV Energia Renováveis S.A. were merged into the Chapada company Piaui II Holding S.A.

            

 

65

 
 

 

DFR - Investor Relations Superintendence
Marketletter - Annex III - 2Q17
Operating Information of the Subsidiaries

IV.3.1 Financing and Loans – R$ Million

                        
                               

Local Currency (LC) + Foreign Currency (FC)

                        

Empresa Eletrobras

Eletrobras (1)

Outros Credores (2)

Total (1+2)

2018

2019

2020

2021

2022

2023

After 2023

2018

2019

2020

2021

2022

2023

After 2023

Eletronorte

258.5

233.6

240.9

233.7

218.9

205.9

718.4

524.3

376.9

335.4

230.2

197.8

199.5

1,507.0

5,481.0

Chesf

305.2

-

-

-

-

-

-

365.4

315.4

155.8

104.0

66.5

63.6

171.9

1,547.8

Furnas

231.0

464.0

486.0

508.0

324.0

112.0

791.0

1,359.0

1,241.0

875.0

621.0

581.0

403.0

717.0

8,713.0

Eletronuclear

254.9

191.4

191.4

147.0

138.1

70.1

515.0

131.9

186.5

199.4

211.6

221.4

236.1

5,164.1

7,859.0

Eletrosul (1)

276.5

256.2

245.9

245.9

245.8

186.0

662.2

168.1

287.6

341.0

402.9

119.2

90.7

244.6

3,772.5

CGTEE

322.1

326.9

326.9

284.6

248.6

220.9

640.8

-

-

-

-

-

-

-

2,370.7

Amazonas GT

47.4

197.0

217.4

216.9

165.0

147.2

143.1

-

-

-

-

-

-

-

1,134.0

Itaipu Binacional

279.9

587.3

626.5

668.8

295.2

58.7

-

486.4

1,021.4

1,090.1

1,163.9

1,240.2

448.4

-

7,966.8

ED Acre (1)

52.2

46.5

46.5

44.5

82.3

55.4

-

-

-

-

-

-

-

-

327.4

ED Alagoas

411.0

367.0

294.0

257.0

127.0

124.0

101.0

2.0

23.0

23.0

23.0

-

-

1.0

1,753.0

ED Amazonas Energia

576.4

278.9

277.8

272.3

269.1

234.0

549.6

-

-

-

-

-

-

-

2,458.1

ED Piauí (1)

470.8

335.5

314.1

266.0

118.3

23.3

82.1

5.4

38.2

38.2

38.2

5.2

5.2

13.9

1,765.4

ED Rondônia

283.8

283.8

269.9

120.5

90.8

76.4

40.3

-

-

-

-

-

-

-

1,165.6

ED Roraima (1)

0.1

0.1

0.0

0.0

0.0

0.0

0.0

-

-

-

-

-

-

-

0.2

(1) It includes promissory notes

                              

 

66

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

Date: August 14, 2017
CENTRAIS ELÉTRICAS BRASILEIRAS S.A. - ELETROBRÁS
By:
/S/ Armando Casado de Araujo
 
Armando Casado de Araujo
Chief Financial and Investor Relation Officer
 
 

 

 
FORWARD-LOOKING STATEMENTS

This press release may contain forward-looking statements. These statements are statements that are not historical facts, and are based on management's current view and estimates offuture economic circumstances, industry conditions, company performance and financial results. The words "anticipates", "believes", "estimates", "expects", "plans" and similar expressions, as they relate to the company, are intended to identify forward-looking statements. Statements regarding the declaration or payment of dividends, the implementation of principal operating and financing strategies and capital expenditure plans, the direction of future operations and the factors or trends affecting financial condition, liquidity or results of operations are examples of forward-looking statements. Such statements reflect the current views of management and are subject to a number of risks and uncertainties. There is no guarantee that the expected events, trends or results will actually occur. The statements are based on many assumptions and factors, including general economic and market conditions, industry conditions, and operating factors. Any changes in such assumptions or factors could cause actual results to differ materially from current expectations.