pbrarmf3q15rs_6k.htm - Generated by SEC Publisher for SEC Filing

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 November, 2015

Commission File Number 1-15106



PETRÓLEO BRASILEIRO S.A. - PETROBRAS
(Exact name of registrant as specified in its charter)



Brazilian Petroleum Corporation - PETROBRAS
(Translation of Registrant's name into English)



Avenida República do Chile, 65
20031-912 - Rio de Janeiro, RJ
Federative Republic of 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____

 


 
 

 

 

THIRD QUARTER OF 2015 RESULTS

Reviewed by independent auditors, stated in millions of Reais, prepared in accordance with International Financial Reporting Standards - IFRS issued by the International Accounting Standards Board – IASB (a free translation of the original in Portuguese).

Rio de Janeiro – November 12, 2015

 

Net income was R$ 2,102 million in Jan-Sep/2015, 58% lower than in Jan-Sep/2014. Loss of R$ 3,759 million in the 3Q-2015.

Operating income was R$ 28,635 million in Jan-Sep/2015, 149% higher than in Jan-Sep/2014.

Adjusted EBITDA was R$ 56,795 million in Jan-Sep/2015, 45% higher than in Jan-Sep/2014.

Net debt was US$ 101,273 million as of September 30, 2015, a 5% decrease when compared to December 31, 2014.

The average maturity of outstanding debt increased from 6.10 years as of December 31, 2014 to 7.49 years as of September 30, 2015.

R$ million

 

 

 

 

 

 

 

 

Jan-Sep

 

 

2015

2014

2015 x 2014 (%)

 

3Q-2015

2Q-2015

3Q15 X 2Q15 (%)

3Q-2014

 

 

 

 

 

 

 

 

2,102

5,013

(58)

Consolidated net income (loss) attributable to the shareholders of Petrobras

(3,759)

531

(808)

(5,339)

28,635

11,504

149

Net income (loss) before finance income (expense), share of earnings in equity-accounted investments, profit sharing and income taxes

5,813

9,487

(39)

(4,921)

56,795

39,083

45

Adjusted EBITDA

15,506

19,771

(22)

8,488

 

 

 

 

 

 

 

 

Net income was R$ 2,102 million in Jan-Sep/2015, 58% lower when compared to Jan-Sep/2014, mainly attributable to higher finance expenses in the Jan-Sep/2015 period. The 149% increase in operating income was mainly a result of higher margins in oil product sales in the domestic market and increased crude oil export volumes driven by a 7% increase in domestic crude oil production, despite a decrease in domestic demand.

Key events in Jan-Sep/2015:

·       6% increase in crude oil and natural gas production (in Brazil and abroad);

·       Higher crude oil export volumes (60%, 132 thousand barrels/day);

·       Lower domestic demand for oil products (8%, 195 thousand barrels/day);

·       Lower import costs and production taxes; and

·       Higher net finance expenses (reaching R$ 23,113 million), as a result of foreign exchange losses and higher interest expense, attributable to an increase in the Company’s debt and a decrease in the level of capitalized borrowing costs, attributable to a lower balance of assets under construction.

Key events in the 3Q-2015, when compared to the 2Q-2015:

·       1% increase in crude oil and natural gas production (in Brazil and abroad);

·       Increased domestic demand for oil products (1%, 32 thousand barrels/day);

·       Lower crude oil export volumes (10%, 40 thousand barrels/day); and

·       A R$ 5,396 million increase in net finance expense as a result of foreign exchange losses.

Foreign exchange depreciation affected our consolidated statement of income, shareholders’ equity and indicators, as estimated below (in R$ million, except indicators):

Consolidated statement of income, shareholders’ equity and indicators items

Effect

Jan-Sep/2015

3Q-2015

 

 

 

 

Net income (loss) - Shareholders of Petrobras

Decrease

10,909

5,208

Adjusted EBITDA

Decrease

6,714

1,822

Cash and cash equivalents held abroad

Increase

28,632

20,496

Debt denominated in foreign currency

Increase

140,840

94,922

Shareholders’ equity

Decrease

30,180

17,699

Net debt/Adjusted EBITDA ratio

Increase

1.77X

1.07X

Leverage

Increase

10.5pp

6.5pp

 

 

 

 

 

 

1


 

 
 

 

 

FINANCIAL AND OPERATING HIGHLIGHTS

Main Items and Consolidated Economic Indicators

R$ million

Jan-Sep

 

 

2015

2014

2015 x 2014

(%)

Results, market capitalization and investments

3Q-2015

2Q-2015

3Q15 X

2Q15 (%)

3Q-2014

 

 

 

 

 

 

 

 

236,535

252,220

(6)

Sales revenues

82,239

79,943

3

88,377

71,727

58,422

23

Gross profit

23,755

25,562

(7)

20,441

28,635

11,504

149

Net income (loss) before finance income (expense), share of earnings in equity-accounted investments, profit sharing and income taxes

5,813

9,487

(39)

(4,921)

(23,113)

(2,086)

(1008)

Net finance income (expense)

(11,444)

(6,048)

(89)

(972)

2,102

5,013

(58)

Consolidated net income (loss) attributable to the shareholders of Petrobras

(3,759)

531

(808)

(5,339)

0.16

0.38

(58)

Basic and diluted earnings (losses) per share 1

(0.29)

0.04

(825)

(0.41)

104,117

229,723

(55)

Market capitalization (Parent Company)

104,117

175,620

(41)

229,723

56,795

39,083

45

Adjusted EBITDA 2

15,506

19,771

(22)

8,488

 

 

 

 

 

 

 

 

30

23

7

Gross margin (%)

29

32

(3)

23

12

7

5

Operating margin (%) 3

7

12

(5)

1

1

2

(1)

Net margin (%)

(5)

1

(6)

(6)

55,489

62,543

(11)

Capital expenditures and investments

19,315

18,331

5

21,043

R$ million

Jan-Sep

 

 

2015

2014

2015 x 2014

(%)

Net income (loss) before finance income (expense), share of earnings in equity-accounted investments, profit sharing and income taxes

3Q-2015

2Q-2015

3Q15 X

2Q15 (%)

3Q-2014

 

 

 

 

 

 

 

 

21,903

(25,176)

187

. Refining, Transportation and Marketing

4,583

7,974

(43)

(11,840)

17,422

46,117

(62)

. Exploration & Production

3,941

8,594

(54)

13,405

2,654

(2,103)

226

. Gas & Power

968

100

868

(3,538)

802

1,199

(33)

. Distribution

(359)

308

(217)

(295)

896

1,088

(18)

. International

(227)

719

(132)

(18)

(174)

(205)

15

. Biofuel

(63)

(66)

5

(67)

(14,525)

(9,661)

(50)

. Corporate

(4,342)

(6,487)

33

(3,586)

 

Jan-Sep

 

 

2015

2014

2015 x 2014

(%)

Indicators

3Q-2015

2Q-2015

3Q15 X

2Q15 (%)

3Q-2014

 

 

 

 

 

 

 

 

224.53

225.74

(1)

Domestic basic oil products price (R$/bbl)

228.15

224.09

2

224.52

174.25

243.95

(29)

Brent crude (R$/bbl)

177.38

190.09

(7)

231.56

55.39

106.57

(48)

Brent crude (US$/bbl)

50.26

61.92

(19)

101.85

 

 

 

 

 

 

 

 

 

 

 

Domestic Sales Price

 

 

 

 

45.04

95.77

(53)

. Crude oil (U.S. dollars/bbl) 4

39.76

52.14

(24)

90.73

37.45

48.76

(23)

. Natural gas (U.S. dollars/bbl)

35.47

39.29

(10)

49.28

 

 

 

 

 

 

 

 

3.17

2.29

38

Average commercial selling rate for U.S. dollar

3.54

3.07

15

2.27

3.97

2.45

62

Period-end commercial selling rate for U.S. dollar

3.97

3.10

28

2.45

49.6

4.6

45

Variation of the period-end commercial selling rate for U.S. dollar (%)

28.1

(3.3)

31

11.3

13.13

10.74

2

Selic interest rate - average (%)

13.99

13.14

1

10.90

 

 

 

 

 

 

 

 

2,232

2,115

6

Total crude oil and NGL production (Mbbl/d)

2,234

2,213

1

2,209

558

512

9

Total natural gas production (Mbbl/d)

566

552

3

537

2,790

2,627

6

Total crude oil and natural gas production (Mbbl/d)

2,800

2,765

1

2,746

3,836

3,951

(3)

Total sales volume (Mbbl/d)

3,889

3,904

4,143

 

 

 

 

 

 

 

 

 


 1Basic and diluted earnings (losses) per share calculated based on the weighted average number of shares.

  2EBITDA + share of earnings in equity-accounted investments, impairment and write-offs of overpayments incorrectly capitalized.

  3Operating margin calculated based on net income (loss) before finance income (expense), share of earnings in equity-accounted investments, profit sharing and income taxes, excluding write-offs of overpayments incorrectly capitalized.

  4 Average between the prices of exports and the internal transfer prices from Exploration & Production to Refining, Transportation and Marketing.

 

 

2


 
 

 

 

 

FINANCIAL AND OPERATING HIGHLIGHTS

RESULTS OF OPERATIONS

Jan-Sep/2015 compared to the Jan-Sep/2014:

Gross profit increased by 23% (R$ 13,305 million) in Jan-Sep/2015 compared to Jan-Sep/2014, mainly due to:

Ø  Sales revenues of R$ 236,535 million, 6% lower, when compared to Jan-Sep/2014, resulting from:

·       Lower crude oil and oil product export prices and decreased domestic price of naphta, jet fuel and fuel oil;

·       Decreased domestic demand for oil products (8%), reflecting lower economic activity in Brazil;

·       Decreased oil product exports (12%);

·       Higher crude oil export volumes (60%) attributable to an increase in domestic crude oil production (7%) and to a decrease in feedstock processed by our domestic refineries (5%); and

·       Higher diesel and gasoline prices, following a price increase in November 2014.

Ø  Cost of sales of R$ 164,808 million in Jan-Sep/2015, 15% lower when compared to Jan-Sep/2014, due to:

·       Lower crude oil and oil product import costs, as well as lower production taxes;

·       Decreased domestic demand for oil products;

·       Lower share of crude oil imports on feedstock processing and a lower share of oil product imports in the sales mix; and

·       Higher crude oil production costs.

 

Net income before finance income (expense), share of earnings in equity-accounted investments, profit sharing and income taxes was R$ 28,635 million in Jan-Sep/2015, 149% higher (R$ 17,131 million) when compared to Jan-Sep/2014, due to:

·       Higher gross profit (R$ 13,305 million);

·       Higher tax expenses (R$ 6,576 million) mainly attributable to the Company’s decision to benefit from a tax amnesty program in 2015 (Programa de Parcelamento Especial de débitos tributários) – see note 20.2 to our 3Q-2015 Financial Statements;

·       Higher legal proceedings expenses (R$ 2,810 million), mainly related to labour and tax claims and a non-recurring positive effect in Jan-Sep/2014 related to a legal proceeding with respect to recoverable taxes (PIS and COFINS overpaid on finance income);

·          Higher pension and medical benefits expenses (retirees) in 2015 attributable to an increase in the Company’s net actuarial liability as a result of a decrease in real interest rates, following the Company’s interim valuation review of its pension and medical benefits in 2014 (R$ 1,333 million);

·       Higher impairment losses attributable to projects removed from the 2015-19 Business and Management Plan investment portfolio (R$ 1,286 million); and

·       Lower write-offs of dry and/or subcommercial wells (R$ 1,037 million).

In addition, non-recurring events affected net income in Jan-Sep/2014:

·       Write-off of overpayments incorrectly capitalized (R$ 6,194 million);

·       Allowance for impairment of trade receivables from companies in the isolated electricity sector (R$ 3,756 million);

·       Write-off of capitalized costs with respect to Premium I and Premium II refineries (R$ 2,707 million); and

·       Expenses related to our Voluntary Separation Incentive Plan - PIDV (R$ 2,455 million).

 

Net finance expense was R$ 23,113 million in Jan-Sep/2015, R$ 21,027 million higher when compared to Jan-Sep/2014, resulting from:

·       Foreign exchange losses of R$ 9,003 million caused by the impact of a 49.6% depreciation of the Brazilian Real against the U.S. dollar on the Company’s net debt (compared to a 4.6% depreciation in Jan-Sep/2014), partially offset by our cash flow hedge, as set out in Appendix 5;

·       Foreign exchange losses of R$ 2,769 million  caused by the impact of a 37.4% depreciation of the Brazilian Real against the Euro on the Company’s net debt (compared to a 4.1% appreciation in Jan-Sep/2014); and

·       Higher interest expenses due to:

i) an increase in the Company’s debt (R$ 4,518 million);

ii) a decrease in the level of capitalized borrowing costs due to a lower balance of assets under construction (R$ 2,067 million), reflecting the relevant projects concluded during 2014 and the write-offs and impairment losses recognized in December 2014; and

iii) interest expenses on tax deficiency notices related to tax on financial operations (Imposto sobre Operações Financeiras – IOF) of R$ 1,418 million and withholding income tax of R$ 1,113 million.

 

Net income attributable to the shareholders of Petrobras was R$ 2,102 million in Jan-Sep/2015, 58% lower (R$ 2,911 million) when compared to Jan-Sep/2014, mainly due to:

 

·       Higher net finance expense;

·       Increased income taxes (R$ 926 million) due to the impact of Brazilian income taxes on income generated by companies incorporated outside Brazil – see note 20.4.1 to our 3Q-2015 Financial Statements; and

·       Higher net income before finance income (expense), share of earnings in equity-accounted investments, profit sharing and income taxes. 

 

3


 
 

 

 

 

FINANCIAL AND OPERATING HIGHLIGHTS

RESULTS OF OPERATIONS

3Q-2015 compared to the 2Q-2015:

Gross profit decreased by 7% (R$ 1,807 million) in the 3Q-2015 when compared to the 2Q-2015, mainly due to:

Ø  Sales revenues were R$ 82,239 million in the 3Q-2015, 3% higher than in the 2Q-2015, resulting from:

·       An increase in domestic demanda for oil products (1%), mainly diesel (3%) and gasoline (1%);

·       Impact of foreign exchange depreciation on exports and operations outside Brazil; and

·       Decreased crude oil exports (10%);

Ø  Costs of sales was R$ 58,484 million in the 3Q-2015, 8% higher when compared to the 2Q-2015, due to:

·       Higher crude oil import costs, higher cost of inputs for production outside Brazil and higher trading costs attributable to a depreciation of the Brazilian Real against the U.S. dollar;

·       Higher oil product sales volumes in the domestic market; and

·       Lower share of oil product imports in the sales mix.

 

Net income before finance income (expense), share of earnings in equity-accounted investments, profit sharing and income taxes was R$ 5,813 million in the 3Q-2015, 39% lower (R$ 3,674 million) when compared to the 2Q-2015, affected by:

·       Lower gross profit (R$ 1,807 million);

·       Higher legal proceedings expenses, mainly related to labour and tax claims (R$ 2,341 million);

·       Impairment charges recognized in the 2Q-2015 attributable to projects removed from the 2015-19 Business and Management Plan investment portfolio (R$ 1,283 million);

·       Lower tax expenses (R$ 905 million) mainly as a result of a decrease in the amounts included in the amnesty program - Programa de Parcelamento Especial de Débitos Tributários in the 3Q-2015, when compared to the 2Q-2015 (see note 20.2 to our 3Q-2015 Financial Statements);

·       Higher write-offs of dry and/or subcommercial wells (R$ 668 million); and

·       Higher expenses with E&P areas returned to ANP (R$ 270 million).

 

Net finance expense was R$ 11,444 million in the 3Q-2015, R$ 5,396 million higher than in the 2Q-2015, due to:

·       Foreign exchange losses of R$ 4,647 million attributable to a 28.1% depreciation of the Brazilian Real against the U.S. dollar and its impact on the Company’s net debt (compared to a 3.3% appreciation in the 2Q-2015); and

·       Foreign exchange losses of R$ 2,001 million resulting from a 28.2% depreciation of the Brazilian Real against the Euro and its impact on the Company’s net debt (compared to a 0.4% depreciation in the 2Q-2015).

 

Net loss attributable to the shareholders of Petrobras was R$ 3,759 million in the 3Q-2015 (compared to a R$ 531 million net income in the 2Q-2015), resulting from higher net finance expense, partially offset by lower income tax expenses (R$ 2,847 million). 

 

4


 
 

 

 

FINANCIAL AND OPERATING HIGHLIGHTS

NET INCOME BY BUSINESS SEGMENT

Petrobras is an integrated energy company and most of the crude oil and natural gas production from the Exploration & Production segment is transferred to other business segments of the Company. Our results by business segment include transactions carried out with third parties, transactions between companies of Petrobras’s  Group and transfers between Petrobras’s business segments that are calculated using internal transfer prices defined through methodologies based on market parameters.

EXPLORATION & PRODUCTION

Jan-Sep

 

 

2015

2014

2015 x 2014 (%)

Net Income

3Q-2015

2Q-2015

3Q15 X 2Q15 (%)

3Q-2014

 

 

 

 

 

 

 

 

10,946

29,592

(63)

 

2,271

5,527

(59)

8,145

 

 

 

 

 

 

 

 

 

(Jan-Sep/2015 x Jan-Sep/2014): The decrease in net income is attributable to a decrease in crude oil sales/transfer prices.

 

The increase in crude oil volume transferred and lower write-offs of dry and/or subcommercial wells partially offset these effects.

 

The Jan-Sep/2014 was affected by the Company’s Voluntary Separation Incentive Plan (PIDV) and of the write-off of overpayments incorrectly capitalized.

 

 

 

 

 

(3Q-2015 x 2Q-2015): Net income was lower, as a result of a decrease in crude oil sales/transfer prices, higher service and freight expenses driven by the depreciation of the Brazilian Real against the U.S. dollar and of an increase in depreciation expense.

Those effects were partially offset by an increase in crude oil volume transferred and lower production taxes.

 

 

 

Jan-Sep

 

 

2015

2014

2015 x 2014 (%)

Exploration & Production - Brazil (Mbbl/d) (*)

3Q-2015

2Q-2015

3Q15 X 2Q15 (%)

3Q-2014

 

 

 

 

 

 

 

 

2,132

1,995

7

Crude oil and NGLs 5

2,136

2,111

1

2,090

469

418

12

Natural gas 6

476

463

3

441

2,601

2,413

8

Total

2,612

2,574

1

2,531

 

 

 

 

 

 

 

 

 

(Jan-Sep/2015 x Jan-Sep/2014): Crude oil and NGL production increased by 7% in Jan-Sep/2015 compared to Jan-Sep/2014 due to the start-ups of FPSOs Cidade de Mangaratiba (Iracema Sul area, Lula field) and Cidade de Ilhabela (Sapinhoá), Cidade de Itaguaí (Iracema Norte, Lula field) and P-61 (Papa-Terra), along with the continuing ramp-ups of P-55 and P-62 (both in Roncador field), P-58 (Parque das Baleias), and of FPSOs Cidade de Paraty (Lula NE) and Cidade de São Paulo (Sapinhoá). This increase was partially offset by the natural decline of production in fields.

The 12% increase in natural gas production is attributable to the production start-up of the units mentioned above and also to the higher productivity of Mexilhão platform and of FPSO Cidade de Santos (Uruguá-Tambaú), which were partially offset by the natural decline of production in fields.

(3Q-2015 x 2Q-2015): Crude oil and NGL production increased by 1% in the 3Q-2015 when compared to the 2Q-2015 due to the production start-up of FPSO Cidade de Itaguaí and to the increased production of FPSOs Cidade de Mangaratiba and Cidade de Ilhabela and of P-58 and P-62 platforms. This increase was partially offset by the scheduled stoppage of P-52 (Roncador) platform in September, which restarted operating on September 16, 2015.

The 3% increase in natural gas production is attributable to the production start-ups and to the increased production of the same units mentioned above.

 

 

 


   (*) Not reviewed by independent auditor.

   5 NGL – Natural Gas Liquids.

   6 Does not include LNG. Includes gas reinjection.

 

 

5


 
 

 

 

 

FINANCIAL AND OPERATING HIGHLIGHTS

 

Jan-Sep

 

 

2015

2014

2015 x 2014 (%)

Lifting Cost 7 - Brazil (*)

3Q-2015

2Q-2015

3Q15 X 2Q15 (%)

3Q-2014

 

 

 

 

 

 

 

 

 

 

 

U.S.$/barrel:

 

 

 

 

12.40

14.70

(16)

Excluding production taxes

11.24

12.71

(12)

15.33

19.62

32.28

(39)

Including production taxes

16.92

21.96

(23)

31.37

 

 

 

 

 

 

 

 

 

 

 

R$/barrel:

 

 

 

 

39.16

33.59

17

Excluding production taxes

40.82

38.49

6

35.18

63.00

74.09

(15)

Including production taxes

64.33

65.95

(2)

73.94

 

 

 

 

 

 

 

 

 Lifting Cost - Excluding production taxes – U.S.$/barrel

(Jan-Sep/2015 x Jan-Sep/2014): Lifting cost excluding production taxes was 16% lower in Jan-Sep/2015 compared to Jan-Sep/2014. Excluding foreign exchange variation effects, lifting cost excluding production taxes increased by 4% due to higher well intervention expenses and higher engineering and subsea maintenance costs in the Campos Basin, partially offset by an increase in crude oil production.

 

 

(3Q-2015 x 2Q-2015 Lifting cost excluding production taxes was 12% lower in the 3Q-2015 compared to the 2Q-2015. Excluding foreign exchange variation effects, it remained relatively flat compared to the 2Q-2015.

 

Lifting Cost - Including production taxes – U.S.$/barrel

(Jan-Sep/2015 x Jan-Sep/2014): Lifting cost including production taxes was 39% lower in Jan-Sep/2015 compared to Jan-Sep/2014, due to lower production taxes (royalties and special participation charges) attributable to a decrease in the average reference price for domestic crude oil in U.S. dollars (a 52% decrease) reflecting lower international crude oil prices and decreased lifting cost mentioned above.

 

 

 

(3Q-2015 x 2Q-2015): Lifting cost including production taxes was 23% lower in the 3Q-2015 compared to the 2Q-2015, mainly resulting from a decrease in the average reference price for domestic crude oil in U.S. dollars (a 23% decrease) reflecting lower international crude oil prices.


(*)  Not reviewed by independent auditor.

 Crude oil and natural gas lifting cost.

6


 
 

 

 

 

FINANCIAL AND OPERATING HIGHLIGHTS

REFINING, TRANSPORTATION AND MARKETING

Jan-Sep

 

 

2015

2014

2015 x 2014

(%)

Net Income

3Q-2015

2Q-2015

3Q15 X

2Q15 (%)

3Q-2014

15,530

(17,594)

188

 

3,727

5,622

(34)

(8,903)

 

 

 

 

 

 

 

 

 

(Jan-Sep/2015 x Jan-Sep/2014): Earnings in Jan-Sep/2015 were attributable to a decrease in crude oil purchase/transfer costs, a lower share of crude oil imports on feedstock processing, to a lower share of oil product imports in our sales mix and diesel (5%) and gasoline (3%) price increases in November 2014.

The loss in Jan-Sep/2014 reflects the non-recurring effect of write-off of overpayments incorrectly capitalized, the write-off of capitalized costs from Premium I and Premium II refineries and our 2014 Voluntary Separation Incentive Plan (PIDV).

 

 

(3Q-2015 x 2Q-2015): Net income was lower as a result of higher tax expenses attributable to a tax deficiency notice related to the alleged failure to withhold income tax (Imposto de renda retido na fonte - IRRF) on amounts Petrobras paid to one of its subsidiaries incorporated outside Brazil with respect to crude oil and oil products imports.

 

 

Jan-Sep

 

 

2015

2014

2015 x 2014

(%)

Imports and Exports of Crude Oil and Oil Products (Mbbl/d) (*)

3Q-2015

2Q-2015

3Q15 X

2Q15 (%)

3Q-2014

 

 

 

 

 

 

 

 

298

399

(25)

Crude oil imports

313

305

3

303

292

414

(29)

Oil product imports

218

315

(31)

410

590

813

(27)

Imports of crude oil and oil products

531

620

(14)

713

351

219

60

Crude oil exports 8

365

405

(10)

323

150

170

(12)

Oil product exports

145

188

(23)

168

501

389

29

Exports of crude oil and oil products

510

593

(14)

491

(89)

(424)

79

Exports (imports) net of crude oil and oil products

(21)

(27)

22

(222)

1

3

(67)

Other exports

1

1

-

5

 

 

 

 

 

 

 

 

 

(Jan-Sep/2015 x Jan-Sep/2014): Crude oil exports were higher due to increased production.

Lower crude oil imports reflect a lower share of crude oil imports in feedstock processing.

Oil product imports decreased as a result of a lower domestic demand.

Oil product exports were lower due to a decrease in feedstock processed.

 

 

(3Q-2015 x 2Q-2015): Lower crude oil exports attributable to the significant level of exports in transit, which were made in September 2015 and will be reognized as sales revenues in the 4Q-2015. In addition, the higher level of exports in the 2Q-2015 is a result of a decrease in inventory levels (from the 1Q-2015).

 

Decreased oil product exports as a result of lower fuel oil production.

Oil product imports decreased due to higher diesel production.

Higher crude oil imports due to increased feedstock processed.

 


(*) Not reviewed by independent auditor.

8  It includes crude oil export volumes made both by our Refining, Transportation and Marketing segment and by our Exploration & Production segment.

7


 
 

 

 

FINANCIAL AND OPERATING HIGHLIGHTS

Jan-Sep

 

 

2015

2014

2015 x 2014

(%)

Refining Operations (Mbbl/d)  (*)

3Q-2015

2Q-2015

3Q15 X

2Q15 (%)

3Q-2014

 

 

 

 

 

 

 

 

2,049

2,170

(6)

Output of oil products

2,085

2,098

(1)

2,204

2,176

2,102

4

Reference feedstock 9

2,176

2,176

2,102

90

98

(8)

Refining plants utilization factor (%) 10

93

92

1

100

1,962

2,059

(5)

Feedstock processed (excluding NGL) - Brazil 11

2,013

1,993

1

2,094

2,002

2,099

(5)

Feedstock processed - Brazil 12

2,052

2,031

1

2,138

86

82

4

Domestic crude oil as % of total feedstock processed

84

86

(2)

80

 

 

 

 

 

 

 

 

 

(Jan-Sep/2015 x Jan-Sep/2014): Feedstock processed was 5% lower, reflecting a decrease in domestic demand, a scheduled stoppage in the distillation unit of Landulpho Alves Refinery (RLAM) and an unscheduled production suspension in REDUC, partially offset by the production start-up of RNEST in November 2014.

 

 

(3Q-2015 x 2Q-2015): Feedstock processed was 1% higher, resulting from the restart of operations at RLAM and REFAP after a scheduled stoppage in the 2Q-2015. This increase was partially offset by a scheduled stoppage in RECAP.

Jan-Sep

 

 

2015

2014

2015 x 2014

(%)

Refining Cost - Brazil  (*)

3Q-2015

2Q-2015

3Q15 X

2Q15 (%)

3Q-2014

 

 

 

 

 

 

 

 

2.52

2.96

(15)

Refining cost (U.S.$/barrel)

2.12

2.64

(20)

3.17

 

 

 

 

 

 

 

 

8.01

6.80

18

Refining cost (R$/barrel)

7.89

7.98

(1)

7.33

 

 

 

 

 

 

 

 

 

(Jan-Sep/2015 x Jan-Sep/2014): Refining cost, in US$/barrel, decreased by 15% in Jan-Sep/2015 when compared to Jan- Sep/2014. Excluding foreign exchange variation effects, refining cost, in R$/barrel, increased by 18%, reflecting higher employee compensation costs attributable to the 2014 Collective Bargaining Agreement, along with a decrease in feedstock processed.

 

 

(3Q-2015 x 2Q-2015): Refining cost, in US$/barrel, decreased by 20%. Refining cost, in R$/barrel, decreased by 1% driven by the restart of operations at RLAM and REFAP after a schedulled stoppage in the 2Q-2015, and to higher feedstock processed in RNEST.

 

 

 

 


(*) Not reviewed by independent auditor.

[9] Reference feedstock or Installed capacity of primary processing considers the maximum sustainable feedstock processing reached at the distillation units at the end of each period, respecting the project limits of equipment and the safety, environment and product quality requirements. It is lower than the authorized capacity set by ANP (including temporary authorizations) and by environmental protection agencies.

[10] Refining plants utilization factor is the feedstock processed (excluding NGL) divided by he reference feedstock.

[11] Feedstock processed (excluding NGL) – Brazil is the volume of crude oil processed in the Company´s refineries and is factored into the calculation of the Refining Plants Utilization Factor.

[12] Feedstock processed – Brazil includes crude oil and NGL processing.

 

8


 
 

 

 

 

 

FINANCIAL AND OPERATING HIGHLIGHTS

GAS & POWER

Jan-Sep

 

 

2015

2014

2015 x 2014 (%)

Net Income

3Q-2015

2Q-2015

3Q15 X 2Q15 (%)

3Q-2014

1,750

(1,293)

235

 

625

90

594

(2,510)

 

 

 

 

 

 

 

 

 

(Jan-Sep/2015 x Jan-Sep/2014): Earnings in Jan-Sep/2015 was generated by an increase in natural gas sales margins, resulting from higher natural gas prices and lower natural gas import costs (LNG and Bolivian gas).

 

The net loss in 2014 was due to impairment of trade receivables from companies in northern Brazil (operating in the isolated electricity system) and write-off of overpayments incorrectly capitalized.

 

 

(3Q-2015 x 2Q-2015): Net income increased due to higher natural gas and electricity sales margins resulting from an increase in natural gas prices driven by a new natural gas pricing policy (discounts were removed) and by a decrease in electricity purchase prices in the spot market, respectively. In addition, 2Q-2015 was affected by impairment losses recognized in a Nitrogen Fertilizers Plant (Unidade de Fertilizantes NitrogenadosUFN V) as a result of a decrease in our investment portfolio in our new 2015-19 Business and Management Plan.

 

Jan-Sep

 

 

2015

2014

2015 x 2014 (%)

Physical and Financial Indicators (*)

3Q-2015

2Q-2015

3Q15 X 2Q15 (%)

3Q-2014

 

 

 

 

 

 

 

 

878

1,201

(27)

Electricity sales (Free contracting market - ACL) 13 - average MW

822

902

(9)

1,196

3,194

2,341

36

Electricity sales (Regulated contracting market - ACR) 14 - average MW

3,058

3,263

(6)

2,671

4,830

4,534

7

Generation of electricity - average MW

4,401

4,987

(12)

4,789

319

657

(51)

Electricity price in the spot market - Differences settlement price (PLD) - R$/MWh 15 

202

369

(45)

671

112

128

(13)

Imports of LNG (Mbbl/d)

92

132

(30)

116

202

206

(2)

Imports of natural gas (Mbbl/d)

196

201

(2)

210

 

 

 

 

 

 

 

 

 

(Jan-Sep/2015 x Jan-Sep/2014): Electricity sales to the Brazilian free contracting market (Ambiente de Contratação Livre – ACL) were 27% lower, attributable to the shift of a portion of our available capacity (1,049 average MW) to the Brazilian regulated market (Ambiente de Contratação Regulada – ACR).

 

Electricity generation was 7% higher due to an increase in the domestic demand for thermal power (coordinated and controlled by the Brazilian Electric System National Operator – Operador Nacional do Sistema ONS) and to an increase in the available capacity of the Petrobras’s Thermal Power Plants Complex.

 

LNG imports decreased by 13% and natural gas imports from Bolivia were 2% lower, reflecting an increase in domestic natural gas supply attributable to a 12% increase in production.

 

Electricity prices in the spot market decreased by 51% as a result of changes in the spot market price regulation established by the Brazilian National Electricity Agency (Agência Nacional de Energia Elétrica ANEEL), which reduced the maximum spot price after December 27, 2014.

 

(3Q-2015 x 2Q-2015): Electricity sales volumes to the Brazilian free contracting market (Ambiente de Contratação Livre – ACL) were 9% lower due to decreased demand.

 

Electricity sales volumes to the Brazilian regulated market (Ambiente de Contratação Regulada – ACR) were 6% lower, as a result of the termination of a sale agreement in 2015 of 205 average MW.

 

Electricity generation decreased by 12% and electricity prices were 45% lower in the spot market due to an improvement in hydrological subsystem conditions and to the decision made by the Electric Sector Monitoring Committee – CMSE (Comitê de Monitoramento do Setor Elétrico) in August 2015, of stopping electricity generatin at power plants with higher unit costs made by, mainly fuel oil plants.

 

LNG imports were 30% lower and natural gas imports from Bolivia were 2% lower resulting from decreased thermoelectric demand.

 

 


(*) Not reviewed by independent auditor.

13 ACL – Ambiente de Contratação Livre (Free contracting market).

14 ACR - Ambiente de Contratação Regulada (Regulated contracting market).

15 Weekly weighed prices per output level (light, medium and heavy), number of hours and submarket capacity.

9


 
 

 

 

 

FINANCIAL AND OPERATING HIGHLIGHTS

DISTRIBUTION

Jan-Sep

 

 

2015

2014

2015 x 2014

(%)

Net Income

3Q-2015

2Q-2015

3Q15 X

2Q15 (%)

3Q-2014

440

753

(42)

 

(299)

184

(263)

(203)

 

 

 

 

 

 

 

 

 

(Jan-Sep/2015 x Jan-Sep/2014): Net income decreased in Jan-Sep/2015 when compared to Jan-Sep/2014 mainly due to lower average trade margins (9.1%) and to a decrease in sales volumes (5%).

The period of Jan-Sep/2014 was impacted by our Voluntary Separation Incentive Plan (PIDV).

 

 

 

 

(3Q-2015 x 2Q-2015): The net loss of the 3Q-2015 was due to a decrease in average trade margins (2.5%) and to higher sales expenses as a result of impairment of trade receivables from companies in the isolated electricity sector.

 

Jan-Sep

 

 

2015

2014

2015 x 2014

(%)

Market Share (*) 16

3Q-2015

2Q-2015

3Q15 X

2Q15 (%)

3Q-2014

35.6%

37.0%

(1)

 

34.7%

35.4%

(1)

37.2%

 

 

 

 

 

 

 

 

 

(Jan-Sep/2015 x Jan-Sep/2014): Market share decreased mainly due to a general increase of the hydrated ethanol market (a 42.2% increase), in which Petrobras Distribuidora has a lower market share and to lower sales to the thermoelectric sector. Other players have also increased their competitiveness by importing gasoline and diesel and purchasing higher volumes of gasoline.

 

 

 

(3Q-2015 x 2Q-2015): Market share was lower mainly due to a decrease in thermoelectric dispatch and to lower market share of non-thermoelectric diesel sales.

 


(*)Not reviewed by independent auditor.

16Beginning in 2015, our market share excludes sales made to wholesalers. Market share for prior periods was revised pursuant to the changes made ​​by the Brazilian National Petroleum, Natural Gas and Biofuels Agency (ANP) and by the Brazilian Wholesalers and Fuel Traders Syndicate (Sindicom). Prior periods are presented based on the new methodology. 

 

10


 
 

 

 

 

FINANCIAL AND OPERATING HIGHLIGHTS

INTERNATIONAL

As a result of the creation of the position of Chief Governance, Risk and Compliance Officer, which replaced the position of Chief International Officer in March, 2015, the Company has approved adjustments to the structure of other business segments to allocate its international activities to those other segments. Considering the necessary steps to integrate the management of those activities, the Company is still presenting the results of international activities separately.

Jan-Sep

 

 

2015

2014

2015 x 2014

(%)

Net Income

3Q-2015

2Q-2015

3Q15 X

2Q15 (%)

3Q-2014

752

927

(19)

 

(167)

816

(120)

(219)

 

 

 

 

 

 

 

 

(Jan-Sep/2015 x Jan-Sep/2014): Net income was lower in Jan-Sep/2015 when compared to Jan-Sep/2014 due to higher selling expenses, write-off of exploration areas returned and impairment charges. In addition, the Company also recognized a gain on disposal of onshore E&P areas in Colombia in Jan-Sep/2014.

This decrease was partially offset by a higher gross profit (when expressed in Reais) attributable to the impact of the depreciation of the Brazilian Real against the U.S. dollar, which was higher than the negative impact of a decrease in international prices.

 

(3Q-2015 x 2Q-2015): The net loss in the 3Q-2015 was mainly a result of a write-off of exploration areas returned and of a non-recurring.positive effect in the 2Q-2015 of tax credits recognized by our Dutch subsidiaries as deferred income taxes in the 2Q-2015.

 

                   

 

Jan-Sep

 

 

2015

2014

2015 x 2014

(%)

Exploration & Production-International (Mbbl/d)17 (*)

3Q-2015

2Q-2015

3Q15 X

2Q15 (%)

3Q-2014

 

 

 

 

 

 

 

 

 

 

 

Consolidated international production

 

 

 

 

70

88

(20)

Crude oil and NGLs

69

71

(3)

86

89

94

(5)

Natural gas

90

89

1

96

159

182

(13)

Total consolidated international production

159

160

(1)

182

30

32

(6)

Non-consolidated international production

29

31

(6)

33

189

214

(12)

Total international production

188

191

(2)

215

 

 

 

 

 

 

 

 

(Jan-Sep/2015 x Jan-Sep/2014): Consolidated international crude oil and NGL production decreased by 20%, reflecting the disposal of onshore areas in Peru in November 2014, in Colombia in April 2014 and in the Austral Basin in Santa Cruz, Argentina, in March 2015. These effects were partially offset by an increase in production due to the start-up of the Saint Malo field in December 2014 and the Lucius field in January 2015 in the United States.

Natural gas production decreased mainly due to the disposal of onshore assets in Peru, in November 2014, and in the Austral Basin in Argentina, in March 2015. These effects were partially offset by the production start-up of the Hadrian South field in the United States in the end of March 2015.

 

 

 

(3Q-2015 x 2Q-2015): Consolidated international crude oil and NGL production decreased by 3%, mainly due to the scheduled stoppage of a platform at Saint Malo field in the Gulf of Mexico in the United States in July 2015.

Natural gas production remained relatively flat when compared to the 2Q-2015.

 

 

 

 

 

 

 

 

 

 

Jan-Sep

 

 

2015

2014

2015 x 2014 (%)

International Sales price

3Q-2015

2Q-2015

3Q15 X 2Q15 (%)

3Q-2014

 

 

 

 

 

 

 

 

58.25

85.46

(32)

. Crude oil (U.S. dollars/bbl)

55.69

60.52

(8)

84.05

23.68

20.83

14

. Natural gas (U.S. dollars/bbl)

25.84

22.66

14

19.06

 

 

 

 

 

 

 

 

 


(*) Not reviewed by independent auditor.

17 Some of the countries that comprise the international production are operating under the production-sharing model, with the production taxes charged in crude oil barrels.

11


 
 

 

 

 

FINANCIAL AND OPERATING HIGHLIGHTS

Jan-Sep

 

 

2015

2014

2015 x 2014 (%)

Lifting Cost - International (U.S.$/barrel) 18 (*)

3Q-2015

2Q-2015

3Q15 X 2Q15 (%)

3Q-2014

7.73

8.55

(10)

 

7.21

7.16

1

8.84

 

 

 

 

 

 

 

 

(Jan-Sep/2015 x Jan-Sep/2014): International lifting cost was 10% lower, mainly in the United States, as a result of the production start-up of the Saint Malo, Lucius and Hadrian South fields that have lower-than-average lifting costs, and to the disposal of onshore assets in Peru and Colombia, which had higher-than-average lifting costs.

 

 

(3Q-2015 x 2Q-2015): International lifting cost remained relatively flat in the period.

 

                   

Jan-Sep

 

 

2015

2014

2015 x 2014 (%)

Refining Operations - International (Mbbl/d) (*)

3Q-2015

2Q-2015

3Q15 X 2Q15 (%)

3Q-2014

 

 

 

 

 

 

 

 

136

168

(19)

Total feedstock processed 19

146

135

8

162

148

181

(18)

Output of oil products

150

140

7

175

230

230

Reference feedstock 20

230

230

230

57

71

(14)

Refining plants utilization factor (%) 21

60

56

4

68

 

 

 

 

 

 

 

 

(Jan-Sep/2015 x Jan-Sep/2014): International feedstock processed was 19% lower due to the interruption of feedstock processing at the Okinawa Refinery in Japan since April 2015, and due to a maintenance scheduled stoppage in the Pasadena Refinery distillation unit in the United States from the beginning of March 2015 to mid-April 2015.

 

 

(3Q-2015 x 2Q-2015): Feedstock processed was 8% higher as a result of an increase in available processing capacity and of the production restart at the Pasadena Refinery in the United States, after a scheduled stoppage in April 2015. This effect was partially offset by the interruption of feedstock processing at the Okinawa Refinery in Japan since April 2015.

                   

Jan-Sep

 

 

2015

2014

2015 x 2014 (%)

Refining Cost - International (U.S.$/barrel) (*)

3Q-2015

2Q-2015

3Q15 X 2Q15 (%)

3Q-2014

4.01

3.81

5

 

4.03

4.08

(1)

4.02

 

 

 

 

 

 

 

 

(Jan-Sep/2015 x Jan-Sep/2014): International refining cost per unit was 5% higher, mainly due to higher employee compensation costs in Argentina and to the interruption of feedstock processing at the Okinawa Refinery in Japan since April 2015, which had lower-than-average costs per unit.

 

(3Q-2015 x 2Q-2015): International refining cost per unit decreased by 1%, due to higher feedstock processing at the atmospheric distillation unit of Pasadena Refinery in the United States, where tests are being made, with respect to the maximum processing capacity of the refinery.

 

                   

BIOFUEL

Jan-Sep

 

 

2015

2014

2015 x 2014 (%)

Net Income

3Q-2015

2Q-2015

3Q15 X 2Q15 (%)

3Q-2014

(463)

(231)

(100)

 

(110)

(304)

64

(90)

 

 

 

 

 

 

 

 

(Jan-Sep/2015 x Jan-Sep/2014): Biofuel losses were higher in Jan-Sep/2015, when compared to Jan-Sep/2014, due to impairment losses in biofuel investees, reflecting changes in the Company’s 2015-2019 Business and Management Plan, partially offset by improved biodiesel trade margins attributable to higher average sales prices and increased sales volumes in 2015.

 

(3Q-2015 x 2Q-2015): Biofuel losses were lower due to impairment losses in biofuel investees in the 2Q-2015 reflecting changes in the Company’s 2015-2019 Business and Management Plan and decreased losses in the ethanol segment in the 3Q-2015.

 

                   

 


(*) Not reviewed by independent auditor.

18 Indicator of crude oil and natural gas lifting cost.

19 Total feedstock processed is the crude oil processed abroad at the atmospheric distillation plants, plus the intermediate products acquired from third parties and used as feedstock in other refining units.

20 Reference feedstock is the maximum sustainable crude oil feedstock reached at distillation plants.

21 Refining Plant Utilization Factor is the crude oil processed at the distillation unit divided by the reference feedstock.

 

 

12


 
 

 

 

FINANCIAL AND OPERATING HIGHLIGHTS

Sales Volumes – (Mbbl/d) (*)

Jan-Sep

 

 

2015

2014

2015 x 2014 (%)

 

3Q-2015

2Q-2015

3Q15 X 2Q15 (%)

3Q-2014

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

928

998

(7)

Diesel

953

923

3

1,049

550

612

(10)

Gasoline

540

537

1

616

106

117

(9)

Fuel oil

97

103

(6)

126

143

167

(14)

Naphtha

137

168

(18)

160

234

235

LPG 22

243

236

3

247

111

110

1

Jet fuel 23

113

107

6

110

182

210

(13)

Others

199

176

13

225

2,254

2,449

(8)

Total oil products

2,282

2,250

1

2,533

123

94

31

Ethanol, nitrogen fertilizers, renewables and other products

134

119

13

98

438

442

(1)

Natural gas

418

448

(7)

449

2,815

2,985

(6)

Total domestic market

2,834

2,817

1

3,080

502

392

28

Exports

511

594

(14)

496

519

574

(10)

International sales

544

493

10

567

1,021

966

6

Total international market

1,055

1,087

(3)

1,063

3,836

3,951

(3)

Total

3,889

3,904

4,143

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

(Jan-Sep/2015 x Jan-Sep/2014): Our domestic sales volumes decreased by 6%, primarily due to:

·           Diesel (a 7% decrease):

i) a lower consumption by infrastructure construction projects in Brazil;

ii) a higher share of diesel sales from other market players (based on diesel imports); and

iii) an increased percentage of mandatory biodiesel content requirement in diesel (diesel/biodiesel mix).

These effects were partially offset by an increase in the Brazilian diesel-moved light vehicle fleet (vans, pick-ups and SUVs);

·           Gasoline (a 10% decrease):

i) an increase in the anhydrous ethanol content requirement for Type C gasoline (from 25% to 27%);

ii) a higher share of gasoline sales from other market players; and

iii) a decrease in the automotive gasoline-moved fleet;

·           Naphtha (a 14% decrease): due to a lower demand by domestic customers, mainly Braskem; and

·           Fuel oil (a 9% decrease): due to lower demand from thermoelectric and industrial sectors in several Brazilian states.

 

(3Q-2015 x 2Q-2015): Our domestic sales volumes increased by 1% when compared to the 2Q-2015, primarily due to:

·       Diesel (a 3% increase): due to seasonal demand, resulting from summer agricultural and industrial activity;

·       Gasoline (a 1% increase): an increase in the Brazilian gasoline-moved light vehicle fleet;

·       Naphtha (an 18% decrease): due to lower demand by domestic customers, mainly Braskem;

·       Natural gas (a 7% decrease): due to a lower demand from thermoelectric sector;

·       LPG (a 3 % increase): due to a decrease in average temperatures; and

·       Jet fuel (a 6 % increase): due to seasonability and lower international jet fuel price.

 

 

                   

(*) Not reviewed by independent auditor.

22 LPG – Liquified crude oil gas.

23 Jet fuel. 

13


 
 

 

 

 

FINANCIAL AND OPERATING HIGHLIGHTS

LIQUIDITY AND CAPITAL RESOURCES

Consolidated Statement of Cash Flows Data – Summary24

R$ million

Jan-Sep

 

 

2015

2014

 

3Q-2015

2Q-2015

3Q-2014

 

 

 

 

 

 

68,946

46,257

Adjusted cash and cash equivalents at the beginning of period 25

91,636

68,182

66,363

(24,707)

(9,085)

Government bonds and time deposits at the beginning of period

(10,470)

(33,732)

(8,223)

44,239

37,172

Cash and cash equivalents at the beginning of period 24

81,166

34,450

58,140

61,133

47,267

Net cash provided by (used in) operating activities

21,816

22,890

23,553

(27,644)

(68,228)

Net cash provided by (used in) investing activities

(11,566)

5,253

(31,111)

(52,810)

(59,606)

Capital expenditures and investments in operating segments

(17,977)

(17,153)

(20,129)

625

1,356

Proceeds from disposal of assets (divestment)

13

96

302

24,541

(9,978)

Investments in marketable securities

6,398

22,310

(11,284)

33,489

(20,961)

(=) Net cash flow

10,250

28,143

(7,558)

(3,087)

41,297

Net financings

(11,668)

18,887

(4,998)

50,049

69,048

Proceeds from long-term financing

12,577

33,737

5,022

(53,136)

(27,751)

Repayments

(24,245)

(14,850)

(10,020)

(8,749)

Dividends paid to shareholders

(18)

315

(56)

Acquisition of non-controlling interest

(190)

109

(57)

24,914

921

Effect of exchange rate changes on cash and cash equivalents

20,312

(423)

4,115

99,870

49,624

Cash and cash equivalents at the end of period 24

99,870

81,166

49,624

4,366

20,635

Government bonds and time deposits at the end of period

4,366

10,470

20,635

104,236

70,259

Adjusted cash and cash equivalents at the end of period 25

104,236

91,636

70,259

 

 

 

 

 

 

As of September 30, 2015, the balance of cash and cash equivalents increased by 126% when compared to the balance as of December 31, 2014 and the balance of adjusted cash and cash equivalents25  for the same period increased by 51% . Our principal uses of funds in Jan-Sep/2015 were for repayment of long-term financing (and interest payments) and for capital expenditures. We met these requirements with cash provided by operating activities of R$ 61,133 million and with proceeds from long-term financing of R$ 50,049 million. The balance of adjusted cash and cash equivalents was positively impacted in 2015 by foreign exchange rate variation applied on our foreign financial investments.

Net cash provided by operating activities increased by 29%  in Jan-Sep/2015 when compared to Jan-Sep/2014, reflecting higher diesel and gasoline prices, increased crude oil export volumes, lower production taxes and decreased crude oil and oil product imports costs, along with a higher share of domestic crude oil on feedstock processing and lower oil product imports.

Capital expenditures and investments in operating segments were 11% lower in Jan-Sep/2015 compared to Jan-Sep/2014, mainly due to a 60% decrease in capital expenditures in our Refining, Transportation and Marketing (RTM) segment. The R$ 24,541 million of divestments in marketable securities relates to proceeds from the maturity of financial investments with maturities longer than three months, most of which were invested in other financial investments, with maturities of less than three months (classified as cash and cash equivalents).

Net cash flow was positive in Jan-Sep/2015 (R$ 33,489 million) compared to a negative net cash flow in Jan-Sep/2014 (R$ 20,961 million).

The Company raised long-term financing of R$ 50,049 million in Jan-Sep/2015, mainly through a US$ 5 billion funding agreement with the Chinese Development Bank (CDB), US$ 2 billion raised through the issuance of Global Notes maturing in 2115, and also through bilateral credit agreements with Brazilian banks. The average maturity of outstanding debt was 7.49 years as of September 30, 2015.

Repayments of interest and principal were R$ 53,136 million in Jan-Sep/2015, 91% higher than in Jan-Sep/2014 and 63% higher in the 3Q-2015 when compared to 2Q-2015.

 


24 For more details, see the Consolidated Statement of Cash Flows Data on page 19.

25 Our adjusted cash and cash equivalents include government bonds and time deposits from highly rated financial institutions abroad with maturities of more than 3 months from the date of acquisition, considering the expected realization of those financial investments in the short-term. This measure is not defined under the International Financial Reporting Standards – IFRS and should not be considered in isolation or as a substitute for cash and cash equivalents computed in accordance with IFRS. It may not be comparable to adjusted cash and cash equivalents of other companies, however management believes that it is an appropriate supplemental measure that helps investors assess our liquidity and supports leverage management.

14


 
 

 

 

FINANCIAL AND OPERATING HIGHLIGHTS

 

Capital expenditures and investments

 

R$ million

 

Jan-Sep

 

2015

%

2014

%

Δ%

 

 

 

 

 

 

Exploration & Production

43,327

78

40,866

65

6

Refining, Transportation and Marketing

5,908

11

13,801

22

(57)

Gas & Power

1,921

3

4,136

7

(54)

International

3,113

6

2,249

4

38

Exploration & Production

2,664

86

1,969

88

35

Refining, Transportation and Marketing

344

11

214

10

61

Gas & Power

43

1

19

1

126

Distribution

55

2

39

2

41

Other

7

8

(13)

Distribution

513

1

708

1

(28)

Biofuel

58

24

142

Corporate

649

1

759

1

(14)

Total capital expenditures and investments

55,489

100

62,543

100

(11)

 

 

 

 

 

 

Pursuant to the Company’s strategic objectives, it operates through joint ventures in Brazil and abroad, as a concessionaire of oil and gas exploration, development and production rights.

The Company invested a total of R$ 55,489 million in Jan-Sep/2015, primarily aiming at increasing crude oil and natural gas production.  

 

15


 
 

 

 

FINANCIAL AND OPERATING HIGHLIGHTS

Consolidated debt

 

R$ million

 

 

 

 

 

09.30.2015

12.31.2014

Δ%

 

 

 

 

 Current debt  26

53,376

31,565

69

 Non-current debt 27

453,208

319,470

42

Total

506,584

351,035

44

Cash and cash equivalents

99,870

44,239

126

Government securities and time deposits (maturity of more than 3 months)

4,366

24,707

(82)

Adjusted cash and cash equivalents

104,236

68,946

51

 Net debt 28

402,348

282,089

43

Net debt/(net debt+shareholders' equity)

58%

48%

10

 Total net liabilities 29

827,326

724,429

14

Capital structure

 

 

 

(Net third parties capital / total net liabilities)

65%

57%

8

Net debt/LTM Adjusted EBITDA ratio 30

5.24

4.77

10

 

 

U.S.$ million

 

 

 

 

 

09.30.2015

12.31.2014

Δ%

 

 

 

 

Current debt 26

13,435

11,884

13

Non-current debt 27

114,075

120,274

(5)

Total

127,510

132,158

(4)

Net debt 28

101,273

106,201

(5)

Average maturity of outstanding debt (years)

7.49

6.10

1.39

 

 

R$ million

 

 

 

 

 

09.30.2015

12.31.2014

Δ%

 

 

 

 

Summarized information on financing

 

 

 

By rate

 

 

 

Floating rate debt

253,141

173,977

46

Fixed rate debt

253,241

176,868

43

Total

506,382

350,845

44

 

 

 

 

By currency

 

 

 

Reais

80,566

62,223

29

US Dollars

376,675

252,787

49

Euro

35,189

25,820

36

Other currencies

13,952

10,015

39

Total

506,382

350,845

44

 

 

 

 

By maturity

 

 

 

2015

17,405

31,523

(45)

2016

50,267

33,397

51

2017

44,787

31,742

41

2018

63,639

47,254

35

2019

89,260

64,252

39

2020 and thereafter

241,024

142,677

69

Total

506,382

350,845

44

 

 

 

 

 

Consolidated net debt in Reais increased by 43% when compared to December 31, 2014, mainly as a result of the 49.6% impact from the depreciation of the Real against the U.S. dollar.

 


26 Includes Finance lease obligations (R$ 44 million on September 30, 2015 and R$ 42 million on December 31, 2014).

27 Includes Finance lease obligations (R$ 158 million on September 30, 2015 and R$ 148 million on December 31, 2014).

28 Net debt is not a measure defined in the International Standards -IFRS and should not be considered in isolation or as a substitute for total long-term debt calculated in accordance with IFRS.  Our calculation of net debt may not be comparable to the calculation of net debt by other companies. Management believes that net debt is an appropriate supplemental measure that helps investors assess our liquidity and supports leverage management.

29 Total liabilities net of adjusted cash and cash equivalents.

30 Beginning in the period ended June 30, 2015, the Company calculated its ratios including Adjusted EBITDA by adding the last four quarters (or Last Twelve Months - LTM Adjusted EBITDA), consistently with the market best practices. The Company previously annualized its Adjusted EBITDA by multiplying the year-to-date amount by the remaining period.

 

16


 
 

 

 

 

FINANCIAL AND OPERATING HIGHLIGHTS

FINANCIAL STATEMENTS

Income Statement - Consolidated31

R$ million

Jan-Sep

 

 

2015

2014

 

3Q-2015

2Q-2015

3Q-2014

 

 

 

 

 

 

236,535

252,220

Sales revenues

82,239

79,943

88,377

(164,808)

(193,798)

Cost of sales

(58,484)

(54,381)

(67,936)

71,727

58,422

Gross profit

23,755

25,562

20,441

(9,465)

(12,230)

Selling expenses

(3,855)

(3,886)

(6,733)

(8,228)

(7,847)

General and administrative expenses

(2,754)

(2,764)

(2,707)

(4,637)

(5,642)

Exploration costs

(2,234)

(1,420)

(2,314)

(1,730)

(1,858)

Research and development expenses

(556)

(610)

(665)

(7,768)

(1,192)

Other taxes

(3,055)

(3,960)

(552)

(6,194)

Write-off - overpayments incorrectly capitalized

(6,194)

(11,264)

(11,955)

Other income and expenses, net

(5,488)

(3,435)

(6,197)

(43,092)

(46,918)

 

(17,942)

(16,075)

(25,362)

28,635

11,504

Net income (loss) before finance income (expense), share of earnings in equity-accounted investments, profit sharing and income taxes

5,813

9,487

(4,921)

3,215

2,974

Finance income

1,866

615

1,174

(15,655)

(6,373)

Finance expenses

(6,403)

(5,561)

(2,282)

(10,673)

1,313

Foreign exchange and inflation indexation charges

(6,907)

(1,102)

136

(23,113)

(2,086)

Net finance income (expense)

(11,444)

(6,048)

(972)

542

991

Share of earnings in equity-accounted investments

200

169

198

(131)

(775)

Profit-sharing

232

(27)

(127)

5,933

9,634

Net income (loss) before income taxes

(5,199)

3,581

(5,822)

(5,522)

(4,596)

Income taxes

174

(2,673)

(117)

411

5,038

Net income (loss)

(5,025)

908

(5,939)

 

 

Net income (loss) attributable to:

 

 

 

2,102

5,013

Shareholders of Petrobras

(3,759)

531

(5,339)

(1,691)

25

Non-controlling interests

(1,266)

377

(600)

411

5,038

 

(5,025)

908

(5,939)

 

 


31 Beginning in 2014, the amount of inventory write-downs to net realizable value (market value) was reclassified from Other Income and Expenses to Cost of Sales.

 

 

17


 
 

 

 

 

 

FINANCIAL AND OPERATING HIGHLIGHTS

Statement of Financial Position – Consolidated

ASSETS

R$ million

 

 

 

 

09.30.2015

12.31.2014

 

 

 

Current assets

176,380

135,023

Cash and cash equivalents

99,870

44,239

Marketable securities

4,379

24,763

Trade and other receivables, net

21,155

21,167

Inventories

32,585

30,457

Recoverable taxes

10,172

10,123

Assets classified as held for sale

295

13

Other current assets

7,924

4,261

 

 

 

Non-current assets

755,182

658,352

Long-term receivables

69,189

50,104

Trade and other receivables, net

17,017

12,834

Marketable securities

341

290

Judicial deposits

8,914

7,124

Deferred taxes

14,753

2,673

Other tax assets

10,681

10,645

Advances to suppliers

7,883

6,398

Other non-current assets

9,600

10,140

Investments

15,987

15,282

Property, plant and equipment

657,873

580,990

Intangible assets

12,133

11,976

Total assets

931,562

793,375

 

 

 

 

 

 

LIABILITIES

R$ million

 

 

 

 

09.30.2015

12.31.2014

 

 

 

Current liabilities

109,719

82,659

Trade payables

26,641

25,924

Current debt

53,376

31,565

Taxes payable

14,011

11,453

Employee compensation (payroll, profit-sharing and related charges)

6,156

5,489

Pension and medical benefits

2,253

2,115

Liabilities associated with assets classified as held for sale

195

Other current liabilities

7,087

6,113

Non-current liabilities

530,861

399,994

Non-current debt

453,208

319,470

Deferred taxes

1,156

8,052

Pension and medical benefits

47,200

43,803

Provision for decommissioning costs

20,176

21,958

Provisions for legal proceedings

6,559

4,091

Other non-current liabilities

2,562

2,620

Shareholders' equity

290,982

310,722

Share capital

205,432

205,432

Profit reserves and others

84,007

103,416

Non-controlling interests

1,543

1,874

Total liabilities and shareholders' equity

931,562

793,375

 

 

 

 

18


 
 

 

 

 

FINANCIAL AND OPERATING HIGHLIGHTS

Statement of Cash Flows Data – Consolidated

R$ million

 

 

 

 

 

 

Jan-Sep

 

 

2015

2014

 

3Q-2015

2Q-2015

3Q-2014

 

 

 

 

 

 

2,102

5,013

Net income (loss) attributable to the shareholders of Petrobras

(3,759)

531

(5,339)

59,031

42,254

(+) Adjustments for:

25,575

22,359

28,892

27,005

21,869

Depreciation, depletion and amortization

9,461

9,028

7,036

22,823

5,507

Foreign exchange and inflation indexation and finance charges

10,952

5,577

2,611

(1,691)

25

Non-controlling interests

(1,266)

377

(600)

(542)

(991)

Share of earnings in equity-accounted investments

(200)

(169)

(198)

6,194

Write-off - overpayments incorrectly capitalized

6,194

566

4,163

Allowance for impairment of trade receivables

542

887

3,954

1,034

3,768

(Gains) / losses on disposal / write-offs of non-current assets, returned areas and cancelled projects

1,223

215

4,081

2,824

2,188

Deferred income taxes, net

(988)

1,768

(108)

3,418

4,262

Exploration expenditures writen-off

1,755

1,087

1,710

2,173

1,404

Impairment of property, plant and equipment, intangible and other assets

844

1,037

931

5,055

3,161

Pension and medical benefits (actuarial expense)

1,687

1,684

909

(843)

189

Inventories

1,811

(1,630)

4,949

273

(4,605)

Trade and other receivables, net

616

(416)

(1,415)

(2,402)

(1,150)

Trade payables

54

(181)

(1,307)

(1,601)

(1,316)

Pension and medical benefits

(479)

(707)

(415)

3,934

(288)

Taxes payable

(2,058)

5,669

1,718

(2,995)

(2,126)

Other assets and liabilities

1,621

(1,867)

(1,158)

61,133

47,267

(=) Net cash provided by (used in) operating activities

21,816

22,890

23,553

(27,644)

(68,228)

(-) Net cash provided by (used in) investing activities

(11,566)

5,253

(31,111)

(52,810)

(59,606)

Capital expenditures and investments in operating segments

(17,977)

(17,153)

(20,129)

625

1,356

Proceeds from disposal of assets (divestment)

13

96

302

24,541

(9,978)

Investments in marketable securities

6,398

22,310

(11,284)

33,489

(20,961)

(=) Net cash flow

10,250

28,143

(7,558)

(2,772)

32,492

(-) Net cash provided by (used in) financing activities

(11,858)

18,996

(5,073)

50,049

69,048

Proceeds from long-term financing

12,577

33,737

5,022

(37,727)

(17,294)

Repayment of principal

(18,281)

(11,005)

(6,226)

(15,409)

(10,457)

Repayment of interest

(5,964)

(3,845)

(3,794)

(8,749)

Dividends paid to shareholders

(18)

315

(56)

Acquisition of non-controlling interest

(190)

109

(57)

24,914

921

Effect of exchange rate changes on cash and cash equivalents

20,312

(423)

4,115

55,631

12,452

(=) Net increase (decrease) in cash and cash equivalents in the period

18,704

46,716

(8,516)

44,239

37,172

Cash and cash equivalents at the beginning of period

81,166

34,450

58,140

99,870

49,624

Cash and cash equivalents at the end of period

99,870

81,166

49,624

 

 

19


 
 

 

 

FINANCIAL AND OPERATING HIGHLIGHTS

SEGMENT INFORMATION

Consolidated Income Statement by Segment – Jan-Sep/2015

 

R$ million

 

 

 

E&P

RTM

GAS & POWER

DISTRIB.

INTER.

BIOFUEL

CORP.

ELIMIN.

TOTAL

 

 

Sales revenues

84,691

176,441

31,218

71,683

22,183

526

(150,207)

236,535

Intersegments

83,360

58,720

5,005

1,354

1,280

488

(150,207)

Third parties

1,331

117,721

26,213

70,329

20,903

38

236,535

Cost of sales

(58,813)

(144,346)

(25,091)

(66,545)

(18,778)

(587)

149,352

(164,808)

Gross profit

25,878

32,095

6,127

5,138

3,405

(61)

(855)

71,727

Expenses

(8,456)

(10,192)

(3,473)

(4,336)

(2,509)

(113)

(14,525)

512

(43,092)

Selling, general and administrative expenses

(1,027)

(5,557)

(1,095)

(4,088)

(1,835)

(79)

(4,528)

516

(17,693)

Exploration costs

(4,273)

(364)

(4,637)

Research and development expenses

(683)

(284)

(137)

(3)

(5)

(25)

(593)

(1,730)

Other taxes

(395)

(2,109)

(981)

(24)

(262)

(3)

(3,994)

(7,768)

Write-off - overpayments incorrectly capitalized

Other income and expenses, net

(2,078)

(2,242)

(1,260)

(221)

(43)

(6)

(5,410)

(4)

(11,264)

Net income (loss) before finance income (expense), share of earnings in equity-accounted investments, profit sharing and income taxes

17,422

21,903

2,654

802

896

(174)

(14,525)

(343)

28,635

Net finance income (expense)

(23,113)

(23,113)

Share of earnings in equity-accounted investments

(574)

1,094

254

(44)

289

(347)

(130)

542

Profit-sharing

(52)

(9)

(68)

(2)

(131)

Net income (loss) before income taxes

16,848

22,945

2,899

690

1,185

(523)

(37,768)

(343)

5,933

Income taxes

(5,924)

(7,430)

(899)

(250)

(188)

60

8,992

117

(5,522)

Net income (loss)

10,924

15,515

2,000

440

997

(463)

(28,776)

(226)

411

Net income (loss) attributable to:

 

 

 

 

 

 

 

 

 

Shareholders of Petrobras

10,946

15,530

1,750

440

752

(463)

(26,627)

(226)

2,102

Non-controlling interests

(22)

(15)

250

245

(2,149)

(1,691)

 

10,924

15,515

2,000

440

997

(463)

(28,776)

(226)

411

 

 

 

 

 

 

 

 

 

 

 

Consolidated Income Statement by Segment – Jan-Sep/201432

 

R$ million

 

 

 

E&P

RTM

GAS & POWER

DISTRIB.

INTER.

BIOFUEL

CORP.

ELIMIN.

TOTAL

 

 

Sales revenues

118,625

198,227

30,491

72,806

25,175

436

(193,540)

252,220

Intersegments

117,882

69,212

2,706

2,013

1,347

380

(193,540)

Third parties

743

129,015

27,785

70,793

23,828

56

252,220

Cost of sales

(60,640)

(209,786)

(26,840)

(66,866)

(22,537)

(523)

193,394

(193,798)

Gross profit

57,985

(11,559)

3,651

5,940

2,638

(87)

(146)

58,422

Expenses

(11,868)

(13,617)

(5,754)

(4,741)

(1,550)

(118)

(9,661)

391

(46,918)

Selling, general and administrative expenses

(633)

(5,246)

(4,302)

(4,396)

(1,349)

(82)

(4,462)

393

(20,077)

Exploration costs

(5,377)

(265)

(5,642)

Research and development expenses

(946)

(315)

(144)

(2)

(3)

(22)

(426)

(1,858)

Other taxes

(76)

(162)

(195)

(21)

(176)

(1)

(561)

(1,192)

Write-off - overpayments incorrectly capitalized

(1,969)

(3,427)

(652)

(23)

(23)

(100)

(6,194)

Other income and expenses, net

(2,867)

(4,467)

(461)

(299)

266

(13)

(4,112)

(2)

(11,955)

Net income (loss) before finance income (expense), share of earnings in equity-accounted investments, profit sharing and income taxes

46,117

(25,176)

(2,103)

1,199

1,088

(205)

(9,661)

245

11,504

Net finance income (expense)

(2,086)

(2,086)

Share of earnings in equity-accounted investments

(6)

316

368

(1)

404

(96)

6

991

Profit-sharing

(269)

(215)

(37)

(45)

(16)

(193)

(775)

Net income (loss) before income taxes

45,842

(25,075)

(1,772)

1,153

1,476

(301)

(11,934)

245

9,634

Income taxes

(16,258)

7,468

506

(400)

(392)

70

4,494

(84)

(4,596)

Net income (loss)

29,584

(17,607)

(1,266)

753

1,084

(231)

(7,440)

161

5,038

Net income (loss) attributable to:

 

 

 

 

 

 

 

 

 

Shareholders of Petrobras

29,592

(17,594)

(1,293)

753

927

(231)

(7,302)

161

5,013

Non-controlling interests

(8)

(13)

27

157

(138)

25

 

29,584

(17,607)

(1,266)

753

1,084

(231)

(7,440)

161

5,038

 

 

 

 

 

 

 

 

 

 

 


32 Beginning in 2014, the amount of inventory write-downs to net realizable value (market value) was reclassified from Other Income and Expenses to Cost of Sales.

 

 

20


 
 

 

 

FINANCIAL AND OPERATING HIGHLIGHTS

Other Income and Expenses, Net by Segment – Jan-Sep/2015

 

R$ million

 

 

 

E&P

RTM

GAS & POWER

DISTRIB.

INTER.

BIOFUEL

CORP.

ELIMIN.

TOTAL

 

 

(Losses)/gains on legal, administrative and arbitral proceedings

(136)

(1,226)

(16)

(162)

(15)

(1,431)

(2,986)

Pension and medical benefits

(2,842)

(2,842)

Unscheduled stoppages and pre-operating expenses

(1,919)

(462)

(223)

(13)

(17)

(2,634)

Impairment

(245)

(365)

(585)

(91)

(1,286)

Institutional relations and cultural projects

(55)

(44)

(4)

(122)

(17)

(809)

(1,051)

Gains / (losses) on disposal/write-offs of assets

(571)

47

(505)

6

404

(8)

(627)

E&P areas returned and cancelled projects

(407)

(407)

Health, safety and environment

(47)

(54)

(15)

(4)

(117)

(237)

Voluntary Separation Incentive Plan - PIDV

(25)

(26)

(51)

1

(4)

(5)

(110)

Governamental Grants

14

14

2

8

38

Amounts recovered - "overpayments incorrectly capitalized"

230

230

(Expenditures)/reimbursements from operations in E&P partnerships

989

989

Others

324

(126)

137

56

(307)

(2)

(419)

(4)

(341)

 

(2,078)

(2,242)

(1,260)

(221)

(43)

(6)

(5,410)

(4)

(11,264)

 Other Income and Expenses, Net by Segment – Jan-Sep/2014 33

 

R$ million

 

 

 

E&P

RTM

GAS & POWER

DISTRIB.

INTER.

BIOFUEL

CORP.

ELIMIN.

TOTAL

 

 

(Losses)/gains on legal, administrative and arbitral proceedings

361

(138)

(24)

(91)

(32)

(1)

(250)

(175)

Pension and medical benefits

(1,509)

(1,509)

Unscheduled stoppages and pre-operating expenses

(1,534)

(45)

(164)

(35)

(29)

(1,807)

Impairment

(306)

15

(291)

Institutional relations and cultural projects

(83)

(52)

(8)

(130)

(14)

(1,050)

(1,337)

Gains / (losses) on disposal/write-offs of assets

(509)

(3,335)

207

28

440

(1)

(105)

(3,275)

E&P areas returned and cancelled projects

(493)

(493)

Health, safety and environment

(51)

(51)

(16)

(7)

(130)

(255)

Voluntary Separation Incentive Plan - PIDV

(995)

(494)

(151)

(159)

(24)

(11)

(621)

(2,455)

Expenses related to collective bargaining agreement

(397)

(226)

(44)

(58)

(11)

(254)

(990)

Governamental Grants

19

57

24

17

117

(Expenditures)/reimbursements from operations in E&P partnerships

542

542

Others

273

(183)

21

111

(66)

(181)

(2)

(27)

 

(2,867)

(4,467)

(461)

(299)

266

(13)

(4,112)

(2)

(11,955)

Consolidated Assets by Segment – 09.30.2015

 

R$ million

 

 

 

E&P

RTM

GAS & POWER

DISTRIB.

INTER.

BIOFUEL

CORP.

ELIMIN.

TOTAL

 

 

Total assets

470,809

182,849

77,008

19,888

49,878

2,393

141,602

(12,865)

931,562

 

 

Current assets

14,124

36,119

9,246

8,506

8,097

201

111,813

(11,726)

176,380

Non-current assets

456,685

146,730

67,762

11,382

41,781

2,192

29,789

(1,139)

755,182

Long-term receivables

21,217

9,131

6,228

4,517

6,634

11

22,425

(974)

69,189

Investments

233

3,512

1,484

47

8,896

1,638

177

15,987

Property, plant and equipment

427,557

133,459

59,067

6,207

24,585

543

6,620

(165)

657,873

Operating assets

309,479

107,676

47,289

5,202

19,856

491

5,773

(165)

495,601

Assets under construction

118,078

25,783

11,778

1,005

4,729

52

847

162,272

Intangible assets

7,678

628

983

611

1,666

567

12,133

 Consolidated Assets by Segment – 12.31.2014

 

R$ million

 

 

 

E&P

RTM

GAS & POWER

DISTRIB.

INTER.

BIOFUEL

CORP.

ELIMIN.

TOTAL

 

 

Total assets

402,478

186,033

75,350

19,180

34,553

2,947

86,024

(13,190)

793,375

 

 

Current assets

15,959

39,111

10,570

9,246

6,229

173

64,174

(10,439)

135,023

Non-current assets

386,519

146,922

64,780

9,934

28,324

2,774

21,850

(2,751)

658,352

Long-term receivables

17,874

9,573

3,749

3,217

4,908

8

13,359

(2,584)

50,104

Investments

531

4,800

1,393

39

5,912

2,221

386

15,282

Property, plant and equipment

360,368

131,914

58,770

6,066

16,091

545

7,403

(167)

580,990

Operating assets

263,794

108,747

47,460

4,595

9,870

502

5,562

(167)

440,363

Assets under construction

96,574

23,167

11,310

1,471

6,221

43

1,841

140,627

Intangible assets

7,746

635

868

612

1,413

702

11,976


33 Beginning in 2014, the amount of inventory write-downs to net realizable value (market value) was reclassified from Other Income and Expenses to Cost of Sales.  

 

21


 
 

 

 

 

FINANCIAL AND OPERATING HIGHLIGHTS

Consolidated Adjusted EBITDA Statement by Segment – Jan-Sep/2015

 

R$ million

 

 

 

E&P

RTM

GAS & POWER

DISTRIB.

INTER.

BIOFUEL

CORP.

ELIMIN.

TOTAL

 

 

Net income (loss)

10,924

15,515

2,000

440

997

(463)

(28,776)

(226)

411

Net finance income (expense)

23,113

23,113

Income taxes

5,924

7,430

899

250

188

(60)

(8,992)

(117)

5,522

Depreciation, depletion and amortization

16,784

5,433

2,117

345

1,683

22

621

27,005

EBITDA

33,632

28,378

5,016

1,035

2,868

(501)

(14,034)

(343)

56,051

Share of earnings in equity-accounted investments

574

(1,094)

(254)

44

(289)

347

130

(542)

Impairment losses / (reversals)

245

365

585

91

1,286

Write-off - overpayments incorrectly capitalized

Adjusted EBITDA

34,451

27,649

5,347

1,079

2,670

(154)

(13,904)

(343)

56,795

 

 

 

 

 

 

 

 

 

 

 Consolidated Adjusted EBITDA Statement by Segment – Jan-Sep/2014

 

R$ million

 

 

 

E&P

RTM

GAS & POWER

DISTRIB.

INTER.

BIOFUEL

CORP.

ELIMIN.

TOTAL

 

 

Net income (loss)

29,584

(17,607)

(1,266)

753

1,084

(231)

(7,440)

161

5,038

Net finance income (expense)

2,086

2,086

Income taxes

16,258

(7,468)

(506)

400

392

(70)

(4,494)

84

4,596

Depreciation, depletion and amortization

12,786

4,821

1,507

297

1,814

21

623

21,869

EBITDA

58,628

(20,254)

(265)

1,450

3,290

(280)

(9,225)

245

33,589

Share of earnings in equity-accounted investments

6

(316)

(368)

1

(404)

96

(6)

(991)

Impairment losses / (reversals)

306

(15)

291

Write-off - overpayments incorrectly capitalized

1,969

3,427

652

23

23

100

6,194

Adjusted EBITDA

60,603

(17,143)

325

1,474

2,894

(184)

(9,131)

245

39,083

 

 

 

 

 

 

 

 

 

 

Consolidated Income Statement for International Segment

 

R$ million

 

 

 

E&P

RTM

GAS & POWER

DISTRIB.

CORP.

ELIMIN.

TOTAL

 

 

Income Statement - Jan-Sep 2015

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Sales revenues

4,562

11,236

1,304

9,950

37

(4,906)

22,183

Intersegments

2,353

3,710

83

4

36

(4,906)

1,280

Third parties

2,209

7,526

1,221

9,946

1

20,903

 

 

Net income (loss) before finance income (expense), share of earnings in equity-accounted investments, profit sharing and income taxes

778

299

161

204

(572)

26

896

 

 

Net income (loss) attributable to the shareholders of Petrobras

847

302

219

172

(814)

26

752

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

R$ million

 

 

 

E&P

RTM

GAS & POWER

DISTRIB.

CORP.

ELIMIN.

TOTAL

 

 

Income Statement - Jan-Sep 2014

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Sales revenues

5,493

13,606

864

8,730

46

(3,564)

25,175

Intersegments

2,175

2,643

60

4

29

(3,564)

1,347

Third parties

3,318

10,963

804

8,726

17

23,828

 

 

Net income (loss) before finance income (expense), share of earnings in equity-accounted investments, profit sharing and income taxes

1,240

(141)

154

261

(404)

(22)

1,088

 

 

Net income (loss) attributable to the shareholders of Petrobras

1,438

(67)

183

241

(846)

(22)

927

 

 

 

 

 

 

 

 

 Consolidated Assets for International Segment

 

R$ million

 

 

 

E&P

RTM

GAS & POWER

DISTRIB.

CORP.

ELIMIN.

TOTAL

 

 

Total assets on September 30, 2015

37,902

6,724

1,867

3,213

4,369

(4,197)

49,878

 

 

Total assets on December 31, 2014

25,557

4,944

1,255

2,497

3,267

(2,967)

34,553

 

 

 

 

 

 

 

 

 

 

22


 
 

 

 

APPENDIX

1.    Reconciliation of Adjusted EBITDA

R$ million

 

Jan-Sep

 

 

2015

2014

2015 X 2014

(%)

 

3Q-2015

2Q-2015

3Q15 X 2Q15 (%)

3Q-2014

 

 

 

 

 

 

 

 

411

5,038

(92)

Net income (loss)

(5,025)

908

(653)

(5,939)

23,113

2,086

1,008

Net finance income (expense)

11,444

6,048

89

972

5,522

4,596

20

Income taxes

(174)

2,673

(107)

117

27,005

21,869

23

Depreciation, depletion and amortization

9,461

9,028

5

7,036

56,051

33,589

67

EBITDA

15,706

18,657

(16)

2,186

(542)

(991)

45

Share of earnings in equity-accounted investments

(200)

(169)

(18)

(198)

1,286

291

-

Impairment losses / (reversals)

1,283

-

306

6,194

(100)

Write-off - overpayments incorrectly capitalized

6,194

56,795

39,083

45

Adjusted EBITDA

15,506

19,771

(22)

8,488

 

 

 

 

 

 

 

 

24

15

9

Adjusted EBITDA margin (%) 34

19

25

(6)

10

 

Our adjusted EBITDA (according to CVM Instruction 527 of October 4, 2012) is the net income before net finance income (expense), income taxes, depreciation, depletion and amortization, share of earnings in equity-accounted investments and impairment, which provides an additional information about our ability to pay debt, carry out investments and cover our working capital needs. Adjusted EBITDA is not an IFRS measure and may not be comparable with the same measure as reported by other companies.

In 2014, the Company decided not to include write-offs of overpayments incorrectly capitalized in the calculation of the Adjusted EBITDA, because the Company’s future cash generation and its current balance of cash and cash equivalents are not impacted by those adjustments. The Company believes excluding those write-offs provides a more appropriate information about its potential cash generation.

 

2.    Effect of weighted average cost flow on the cost of sales (R$ million)

Products remain in inventory for an average of 60 days and, therefore, the changes on international crude oil and oil products prices and the effect of the exchange rate variation on imports and on production taxes do not fully impact the costs of sales for the period, fully impacting only the following period. The estimated effects on the cost of sales are set out in the table below:                                                                                         

                                                                                                                                                                                                                                                                     R$ million

 

2Q-2015

3Q-2015

Δ *

Effect of the average cost on the cost of sales *

1,067

28

(1,040)

 

* The cost of sales of the 3Q-2015 compared to the 2Q-2015 was less favored by the effect of the average cost of inventories.

( ) The amount in parenthesis demonstrates the negative effect on the cost of sales.

 

 


34 Adjusted EBITDA margin equals Adjusted EBITDA divided by sales revenues.

 

 

23


 
 

 

 

 

APPENDIX

3. Production Taxes

R$ million

Jan-Sep

 

 

2015

2014

2015 x 2014

(%)

 

3Q-2015

2Q-2015

3Q15 X

2Q15 (%)

3Q-2014

 

 

 

 

 

 

 

 

 

 

 

Brazil

 

 

 

 

8,472

12,089

(30)

Royalties

2,846

3,097

(8)

4,041

6,489

11,723

(45)

Special participation charges

2,132

2,593

(18)

4,026

127

124

2

Rental of areas

43

41

5

42

15,088

23,936

(37)

Subtotal - Brazil

5,021

5,731

(12)

8,109

724

891

(19)

International

276

230

20

290

15,812

24,827

(36)

Total

5,297

5,961

(11)

8,399

 

 

 

 

 

 

 

 

(Jan-Sep/2015 x Jan-Sep/2014): Production taxes in Brazil decreased 37% mainly due to the 35% decrease in the reference price for domestic oil in Reais that reached an average of R$/bbl 141.28 (US$/bbl 44.99) in Jan-Sep/2015 compared to R$/bbl 216.08 (US$/bbl 94.42) in Jan-Sep/2014, reflecting international crude oil prices. These effects were partially offset by higher production.

 

(3Q-2015 x 2Q-2015): Production taxes in Brazil decreased 12% mainly due to the 12% decrease in the reference price for domestic oil in Reais that reached an average of R$/bbl 139.60 (US$/bbl 39.62) in the 3Q-2015 compared to R$/bbl 157.91 (US$/bbl 51.41) in the 2Q-2015, reflecting international crude oil prices.

                   

4. Impact of our Cash Flow Hedge policy

 

R$ million

Jan-Sep

 

 

2015

2014

2015 x 2014

(%)

 

3Q-2015

2Q-2015

3Q15 X

2Q15 (%)

3Q-2014

 

 

 

 

 

 

 

 

(79,066)

(3,091)

(2,458)

Total inflation indexation and foreign exchange variation

(54,673)

5,748

(1,051)

(11,813)

72,586

5,456

1,230

Deferred Foreign Exchange Variation recognized in Shareholders' Equity

49,628

(5,343)

1,029

12,231

(4,193)

(1,052)

(299)

Reclassification from Shareholders’ Equity to the Statement of Income

(1,862)

(1,507)

(24)

(282)

(10,673)

1,313

(913)

Net Inflation indexation and foreign exchange variation

(6,907)

(1,102)

(527)

136

 

 

 

 

 

 

 

 

 

The amounts recycled from the Shareholders’ Equity to the income statement with respect to foreign exchange variation losses initially recognized in the Shareholders’ equity (cash flow hedge accounting) increased from R$ 1,507 million in the 2Q-2015 to R$ 1,862 million in the 3Q-2015, reflecting the occurrence of the hedged transactions (exports hedged by debt denominated in U.S. dollars). Those losses were driven by a depreciation of the Real between the date the cash flow hedge relationship was designated and the date the export transactions were made.

 

 

24


 
 

 

 

 

APPENDIX

5.    Assets and Liabilities subject to Exchange Variation

The Company has assets and liabilities subject to foreign exchange rate variation, for which the main exposure is to the Real relative to the U.S. dollar and the U.S. dollar relative to the Euro. Beginning in mid-May 2013, the Company extended the use of hedge accounting to hedge highly probable future exports.

The Company designates hedging relationships between exports and its long-term debt obligations (denominated in U.S. dollars) to simultaneously recognize the effects of the existing natural foreign exchange hedge between those operations in its financial statements.

Through the extension of the hedge accounting practice, foreign exchange gains or losses from debt denominated in U.S. dollars, generated by foreign exchange variation, are recognized in our shareholders’ equity and will only affect the statement of income at the moment of realization of future exports.

The balances of assets and liabilities in foreign currency of our foreign subsidiaries are not included in our foreign exchange rate variation exposure below when transacted in a currency equivalent to their respective functional currencies. As of September 30, 2015, the Company had a net liability exposure to foreign exchange rates. Therefore, the appreciation of the Real relative to other currencies results in a foreign exchange variation gain, while the depreciation of the Real results in a foreign exchange variation loss.

ITEMS

R$ million

 

 

 

 

09.30.2015

12.31.2014

 

 

 

Assets

40,932

30,600

Liabilities

(334,222)

(222,279)

Hedge Accounting

229,101

135,088

Total

(64,189)

(56,591)

 

 

 

 

BY CURRENCY

R$ million

 

 

 

 

09.30.2015

12.31.2014

 

 

 

Real/ U.S. Dollars

(14,601)

(20,844)

Real/ Euro

(9,042)

(6,860)

Real/ Pound Sterling

(2,710)

(1,919)

U.S. Dollars/ Yen

(2,402)

(1,728)

U.S. Dollars/ Euro

(25,716)

(18,562)

U.S. Dollars/ Pound Sterling

(7,981)

(5,376)

Peso/ U.S. Dollars

(1,737)

(1,302)

Total

(64,189)

(56,591)

 

 

 

 

MAIN FOREIGN EXCHANGE VARIATION EXPOSURES 2015 x 2014

%

 

 

Real x U.S. dollar

49.57% depreciation of the Real

Real x Euro

37.43% depreciation of the Real

U.S. dollar x Euro

8.12% appreciation of U.S. dollar

U.S. dollar x Libra

3.03% appreciation of U.S. dollar

 

 

25


 
 

 

 

 

APPENDIX

6. Special items

R$ million

Jan-Sep

 

 

 

 

 

2015

2014

 

Items of Income Statement

3Q-2015

2Q-2015

3Q-2014

             

(7,501)

-

Federal Tax Amnesty Program (REFIS)

Several

(3,128)

(4,373)

-

(1,606)

2,683

(Losses)/Gains on legal proceedings

Several

(1,865)

259

2,683

(1,286)

(2,998)

Impairment/Write-offs of Assets

Other income and expenses

-

(1,283)

(3,013)

(822)

-

Tax amnesty programs - State Tax

Several

(302)

-

-

(110)

(2,455)

Voluntary Separation Incentive Plan – PIDV

Other income and expenses

(29)

(55)

(79)

633

(3,756)

(Allowance)/reversal of allowance for impairment of trade receivables from companies in the isolated electricity system

Selling expenses

(492)

(46)

(3,756)

464

871

Gains/(Losses) on Disposal of Assets

Other income and expenses

-

-

-

230

-

Amounts recovered - "overpayments incorrectly capitalized"

Other income and expenses

73

157

 

-

(6,194)

Write-off - overpayments incorrectly capitalized

Specific line item

-

-

(6,194)

(9,998)

(11,849)

Total

 

(5,743)

(5,341)

(10,359)

Impact of the Company’s decision to adhere to the benefits of a Federal Tax Amnesty Program (Programa de Parcelamento Especial de Débitos Tributários - REFIS) on its Income Statement:

(5,027)

-

Tax expense

 

(1,955)

(3,072)

-

(2,474)

-

Interest expense

 

(1,173)

(1,301)

-

(7,501)

-

Federal Tax amnesty program (REFIS)

 

(3,128)

(4,373)

-

Impact of the Company’s decision to adhere to the benefits of a Tax Amnesty Program - State Tax on the Company’s Income Statement:

(723)

-

Tax expense

 

(282)

-

-

(99)

-

Interest expense

 

(20)

-

-

(822)

-

Tax amnesty programs - State Tax

 

(302)

-

-

Impact of (losses)/gains on legal proceedings on the Company’s Income Statement:

(1,606)

1,326

Other income and expenses

 

(1,865)

259

1,326

-

1,357

Inflation indexation and foreign exchange variation

 

-

-

1,357

(1,606)

2,683

(Losses)/Gains on legal proceedings

 

(1,865)

259

2,683

These special items are related to the Company’s businesses and based on Management’s judgment have been highlighted and are presented as additional information to provide a better understanding of the Company’s performance. These items are presented when relevant and do not necessarily occur in all periods.

 

 

26

 


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: November 13, 2015
PETRÓLEO BRASILEIRO S.A--PETROBRAS
By:
/S/  Ivan de Souza Monteiro

 
Ivan de Souza Monteiro
Chief Financial Officer and Investor Relations Officer
 
 

 

 
FORWARD-LOOKING STATEMENTS

This press release may contain forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended (Securities Act), and Section 21E of the Securities Exchange Act of 1934, as amended (Exchange Act) that are not based on historical facts and are not assurances of future results.  These forward-looking statements are based on management's current view and estimates of future 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 o f 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. 
All forward-looking statements are expressly qualified in their entirety by this cautionary statement, and you should not place reliance on any forward-looking statement contained in this press release. We undertake no obligation to publicly update or revise any forward-looking statements, whether as a result of new information or future events or for any other reason.