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____.
Campinas, May 15, 2018 – CPFL Energia S.A. (B3: CPFE3 and NYSE: CPL), announces its 1Q18 results. The financial and operational information herein, unless otherwise indicated, is presented on a consolidated basis and is in accordance with the applicable legislation. Comparisons are relative to 1Q17, unless otherwise stated.
CPFL ENERGIA ANNOUNCES ITS 1Q18 RESULTS
Indicators (R$ Million) |
1Q18 |
1Q17 |
Var. |
Sales within the Concession Area - GWh |
17,190 |
16,708 |
2.9% |
Captive Market |
11,989 |
12,096 |
-0.9% |
Free Client |
5,201 |
4,611 |
12.8% |
Gross Operating Revenue |
9,637 |
8,730 |
10.4% |
Net Operating Revenue |
6,375 |
5,539 |
15.1% |
EBITDA(1) |
1,366 |
1,196 |
14.3% |
Net Income |
419 |
232 |
80.7% |
Investments(2) |
426 |
681 |
-37.4% |
|
|
|
|
Notes:
(1) EBITDA is calculated from the sum of net income, taxes, financial result, depreciation/amortization, as CVM Instruction no. 527/12. See the calculation in item 4.6 of this report;
(2) Includes investment related to the construction of transmission lines of CPFL Transmissão Morro Agudo and, according to the requirements of IFRIC 12, it was recorded as “Financial Asset of Concession” (in non-current assets). Does not include special obligations.
1Q18 HIGHLIGHTS
• Increase in sales within the concession area (+2.9%), highlighting the growth of the industrial class (5,8%);
• Increases of 15.1% in Net Operating Revenue and of 14.3% in EBITDA;
• Net debt of R$ 15.6 billion and leverage of 3.31x Net Debt/EBITDA;
• Funding totalizing R$ 2.8 billion in 1Q18, at competitive costs;
• Investments of R$ 426 million in 1Q18;
• Conclusion of CPFL Paulista’s tariff revision, in Apr-18, with an average effect of +16.90% to be perceived by the consumers;
• Conclusion of RGE Sul’s tariff revision, in Apr-18, with an average effect of +22.47% to be perceived by the consumers.
Conference Call with Simultaneous Translation into English · Wednesday, May 16, 2017 – 11:00 a.m. (Brasília), 10:00 a.m. (ET) ( Portuguese: 55-11-3193-1001 or 55-11-2820-4001 (Brazil) ( English: 1-800-492-3904 (USA) and 1-646-828-8246 (Other Countries) |
Investor Relations 55-19-3756-8458 www.cpfl.com.br/ir |
INDEX
1) MESSAGE FROM THE CEO |
4 |
|
|
2) ENERGY SALES |
5 |
2.1) Sales within the Distributors’ Concession Area |
5 |
2.1.1) Sales by Segment – Concession Area |
6 |
2.1.2) Sales to the Captive Market |
6 |
2.1.3) Free Clients |
6 |
2.2) Generation Installed Capacity |
7 |
|
|
3) INFORMATION ON INTEREST IN COMPANIES AND CRITERIA OF FINANCIAL STATEMENTS CONSOLIDATION |
8 |
3.1) Consolidation of CPFL Renováveis Financial Statements |
10 |
3.2) Consolidation of RGE Sul Financial Statements |
10 |
3.3) Economic-Financial Performance Presentation |
10 |
3.4) Consolidation of Transmission Companies |
10 |
|
|
4) ECONOMIC-FINANCIAL PERFORMANCE |
11 |
4.1) Opening of economic-financial performance by business segment |
11 |
4.2) Sectoral Financial Assets and Liabilities |
12 |
4.3) Operating Revenue |
12 |
4.4) Cost of Electric Energy |
13 |
4.5) Operating Costs and Expenses |
14 |
4.6) EBITDA |
15 |
4.7) Financial Result |
16 |
4.8) Net Income |
17 |
|
|
5) INDEBTEDNESS |
18 |
5.1) Debt (IFRS) |
18 |
5.1.1) Debt Amortization Schedule in IFRS (Mar-18) |
19 |
5.2) Debt in Financial Covenants Criteria |
20 |
5.2.1) Indexation and Debt Cost in Financial Covenants Criteria |
20 |
5.2.2) Net Debt in Financial Covenants Criteria and Leverage |
21 |
|
|
6) INVESTMENTS |
22 |
6.1) Actual Investments |
22 |
6.2) Investments Forecasts |
22 |
|
|
7) ALLOCATION OF RESULTS |
23 |
|
|
8) STOCK MARKETS |
24 |
8.1) Stock Performance |
24 |
8.2) Daily Average Volume |
24 |
|
|
9) CORPORATE GOVERNANCE |
25 |
|
|
10) SHAREHOLDERS STRUCTURE |
26 |
|
|
11) PERFORMANCE OF THE BUSINESS SEGMENTS |
27 |
11.1) Distribution Segment |
27 |
11.1.1) Economic-Financial Performance |
27 |
11.1.1.1) Sectoral Financial Assets and Liabilities |
27 |
11.1.1.2) Operating Revenue |
28 |
11.1.1.3) Cost of Electric Energy |
29 |
11.1.1.4) Operating Costs and Expenses |
30 |
11.1.1.5) EBITDA |
32 |
|
|
Página 2 de 59
11.1.1.6) Financial Result |
32 |
11.1.1.7) Net Income |
33 |
11.1.2) Tariff Events |
33 |
11.1.3) Operating Indicators |
36 |
11.2) Commercialization and Services Segments |
38 |
11.2.1) Commercialization Segment |
38 |
11.2.2) Services Segment |
39 |
11.3) Conventional Generation Segment |
39 |
11.3.1) Economic-Financial Performance |
39 |
11.3.1.1) Operating Revenue |
40 |
11.3.1.2) Cost of Electric Power |
40 |
11.3.1.3) Operating Costs and Expenses |
41 |
11.3.1.4) Equity Income |
42 |
11.3.1.5) EBITDA |
43 |
11.3.1.6) Financial Result |
43 |
11.3.1.7) Net Income |
44 |
11.4) CPFL Renováveis |
45 |
11.4.1) Economic-Financial Performance |
45 |
11.4.1.1) Variations in the Income Statement of CPFL Renováveis |
45 |
11.4.1.2) Operating Revenue |
45 |
11.4.1.3) Cost of Electric Power |
45 |
11.4.1.4) Operating Costs and Expenses |
46 |
11.4.1.5) EBITDA |
46 |
11.4.1.6) Financial Result |
47 |
11.4.1.7) Net Income |
47 |
11.4.2) Status of Generation Projects – 100% Participation |
48 |
|
|
12) ATTACHMENTS |
49 |
12.1) Statement of Assets – CPFL Energia |
49 |
12.2) Statement of Liabilities – CPFL Energia |
50 |
12.3) Income Statement – CPFL Energia |
51 |
12.4) Cash Flow – CPFL Energia |
52 |
12.5) Income Statement – Conventional Generation Segment |
53 |
12.6) Income Statement – CPFL Renováveis |
54 |
12.7) Income Statement – Distribution Segment |
55 |
12.8) Economic-Financial Performance by Distributor |
56 |
12.9) Sales within the Concession Area by Distributor (In GWh) |
57 |
12.10) Sales to the Captive Market by Distributor (in GWh) |
58 |
12.11) Reconciliation of Net Debt/EBITDA Pro Forma ratio of CPFL Energia for purposes of financial covenants calculation |
59 |
Página 3 de 59
The results of CPFL Group in the first quarter of 2018 reflected the signs of a resumption of activity in several segments of the economy in the period, as well as our operational discipline and the recent falls in the interest rate in Brazil.
The distribution segment registered growth in energy sales (+2.9%). Residential, industrial and commercial classes registered market variations of 0.8%, 5.8% and 0.1%, respectively, being positively impacted by the slow recovery of economy activity.
CPFL Group’s operating cash generation, measured by EBITDA, reached R$ 1,366 million in 1Q18 (+14.3%), reflecting the positive results from the Distribution and Conventional Generation segments. In addition, the Company is promoting organizational reviews in order to simplify its processes and structure, aiming at greater focus on business.
It is also worth highlighting the conclusion of the tariff revision process (4th cycle) of CPFL Paulista and RGE Sul, in April 2018, with an average effect to be perceived by the consumers of +16.90% and +22.47%, respectively.
We continue working on value initiatives and in our investment plan in the first quarter (around R$ 10.4 billion for the next 5 years, being R$ 2.1 billion for 2018), with financial discipline, efforts and commitment of our teams. We invested R$ 426 million in this period.
CPFL Energia’s capital structure and consolidated leverage remained at adequate levels. The Company’s net debt reached 3.31 times EBITDA at the end of the quarter, under the criteria to measure our financial covenants, below the 3.75x limit. It is worth mentioning that the reductions in interest rates have benefited the Company.
Finally, CPFL’s management remains optimistic about the advances of the Brazilian electricity sector and remains confident in its business platform, which is increasingly prepared and well positioned to face the challenges and opportunities in the country.
Andre Dorf
CEO of CPFL Energia
Página 4 de 59
Sales within the Concession Area - GWh | |||
|
1Q18 |
1Q17 |
Var. |
Captive Market |
11,989 |
12,096 |
-0.9% |
Free Client |
5,201 |
4,611 |
12.8% |
Total |
17,190 |
16,708 |
2.9% |
In 1Q18, sales within the concession area, achieved by the distribution segment, totaled 17,190 GWh, an increase of 2.9%, highlighting the growth of the Industrial class (+5.8%), especially at CPFL Paulista (+5.6%) and CPFL Piratininga (+7.8%).
Sales to the captive market totaled 11,989 GWh in 1Q18, a reduction of 0.9%. The quantity of energy, in GWh, which corresponds to the consumption of free clients in the concession area of group’s distributors, billed through the Tariff for the Usage of the Distribution System (TUSD), reached 5,201 GWh in 1Q18, an increase of 12.8%, reflecting the migration of customers to the free market.
Sales within the Concession Area - GWh | ||||
|
1Q18 |
1Q17 |
Var. |
Part. |
Residential |
5,172 |
5,129 |
0.8% |
30.1% |
Industrial |
5,994 |
5,664 |
5.8% |
34.9% |
Commercial |
2,945 |
2,944 |
0.1% |
17.1% |
Others |
3,079 |
2,972 |
3.6% |
17.9% |
Total |
17,190 |
16,708 |
2.9% |
100.0% |
Note: The tables with sales within the concession area by distributor are attached to this report in item 12.9. |
Noteworthy in 1Q18, in the concession area:
· Industrial class (34.9% of total sales): increase of 5.8%, reflecting the positive performance of the main industrial activities in the concession area of CPFL Energia (metallurgy, vehicles, chemicals and pulp and paper);
· Residential and commercial classes (30.1% and 17.1% of total sales, respectively): increases of 0.8% and 0.1%, respectively. The low temperatures recorded in January and February of 2018 contributed to the fall in the CPC (Consumption per Consumer - GWh/CU/month) in the quarter (-1.3%).
Página 5 de 59
Note: in parentheses, the variation in percentage points from 1Q17 to 1Q18
Sales to the Captive Market - GWh | |||
|
1Q18 |
1Q17 |
Var. |
Residential |
5,172 |
5,129 |
0.8% |
Industrial |
1,504 |
1,631 |
-7.8% |
Commercial |
2,323 |
2,442 |
-4.9% |
Others |
2,990 |
2,894 |
3.3% |
Total |
11,989 |
12,096 |
-0.9% |
Note: The tables with captive market sales by distributor are attached to this report in item 12.10. |
The reduction of 0.9% (107 GWh) in sales to the captive market, from 12,096 GWh in 1Q17 to 11,989 GWh in 1Q18, was influenced by the performance of the industrial (-7.8%) and commercial (-4.9%) classes, reflecting the migration of customers to the free market.
Free Client - GWh | |||
|
1Q18 |
1Q17 |
Var. |
Industrial |
4,490 |
4,033 |
11.3% |
Commercial |
622 |
501 |
24.1% |
Others |
90 |
77 |
16.0% |
Total |
5,201 |
4,611 |
12.8% |
Página 6 de 59
Free Client by Distributor - GWh | |||
|
1Q18 |
1Q17 |
Var. |
CPFL Paulista |
2,434 |
2,177 |
11.8% |
CPFL Piratininga |
1,529 |
1,335 |
14.6% |
RGE |
568 |
534 |
6.4% |
RGE Sul |
525 |
454 |
15.6% |
CPFL Santa Cruz |
145 |
112 |
29.9% |
Total |
5,201 |
4,611 |
12.8% |
2.2) Generation Installed Capacity
In 1Q18, the installed capacity of generation of CPFL Energia, considering the proportional stake in each project, reached 3,283 MW, representing an expansion of 0.8%. This increase is due to the commercial start-up of Pedra Cheirosa Wind Complex.
Generation Installed Capacity | MW
Note: Take into account CPFL Energia’s 51.6% stake in CPFL Renováveis.
Página 7 de 59
The interests directly or indirectly held by CPFL Energia in its subsidiaries and jointly-owned entities are described below. Except for: (i) the jointly-owned entities ENERCAN, BAESA, Foz do Chapecó and EPASA, that, as from January 1, 2013 are no longer proportionally consolidated in the Company’s financial statements, being their assets, liabilities and results accounted for using the equity method of accounting, and (ii) the investment in Investco S.A. recorded at cost by the subsidiary Paulista Lajeado, the other units are fully consolidated.
As of March 31, 2018 and 2017, the participation of non-controlling interests stated in the consolidated statements refers to the third-party interests in the subsidiaries CERAN, Paulista Lajeado and CPFL Renováveis.
Since November 1st, 2016 CPFL Energia is considering the full consolidation of RGE Sul.
Energy distribution |
Company Type |
Equity Interest |
Location (State) |
Number of municipalities |
Approximate number of consumers |
Concession term |
End of the concession |
Companhia Paulista de Força e Luz ("CPFL Paulista") |
Publicly-quoted corporation |
Direct |
Interior de São Paulo |
234 |
4,413 |
30 years |
November 2027 |
Companhia Piratininga de Força e Luz ("CPFL Piratininga") |
Publicly-quoted corporation |
Direct |
Interior e litoral de São Paulo |
27 |
1,728 |
30 years |
October 2028 |
Rio Grande Energia S.A. ("RGE") |
Publicly-quoted corporation |
Direct |
Interior do Rio Grande do Sul |
255 |
1,491 |
30 years |
November 2027 |
RGE Sul Distribuidora de Energia S.A. ("RGE Sul") |
Publicly-quoted corporation |
Indirect |
Interior do Rio Grande do Sul |
118 |
1,347 |
30 years |
November 2027 |
Companhia Jaguari de Energia ("CPFL Santa Cruz") (d) |
Private corporation |
Direct |
Interior de São Paulo, Paraná e Minas Gerais |
45 |
449 |
30 years |
July 2045 |
Energy generation (conventional and renewable sources) |
Company Type |
Equity Interest |
Location (State) |
Number of plants / type of energy |
Installed capacity | |
Total |
CPFL participation | |||||
CPFL Geração de Energia S.A. ("CPFL Geração") |
Publicly-quoted corporation |
Direct |
São Paulo and Goiás |
3 Hydroelectric (a) |
1,295 |
678 |
CERAN - Companhia Energética Rio das Antas ("CERAN") |
Private corporation |
Indirect |
Rio Grande do Sul |
3 Hydroelectric |
360 |
234 |
Foz do Chapecó Energia S.A. ("Foz do Chapecó") |
Private corporation |
Indirect |
Santa Catarina and |
1 Hydroelectric |
855 |
436 |
Campos Novos Energia S.A. ("ENERCAN") |
Private corporation |
Indirect |
Santa Catarina |
1 Hydroelectric |
880 |
429 |
BAESA - Energética Barra Grande S.A. ("BAESA") |
Publicly-quoted corporation |
Indirect |
Santa Catarina and |
1 Hydroelectric |
690 |
173 |
Centrais Elétricas da Paraíba S.A. ("EPASA") |
Private corporation |
Indirect |
Paraíba |
2 Thermoelectric |
342 |
182 |
Paulista Lajeado Energia S.A. ("Paulista Lajeado") |
Private corporation |
Indirect |
Tocantins |
1 Hydroelectric |
903 |
63 |
CPFL Energias Renováveis S.A. ("CPFL Renováveis") |
Publicly-quoted corporation |
Indirect |
See chapter 11.4.2 |
See chapter 11.4.2 |
See chapter 11.4.2 |
See chapter 11.4.2 |
CPFL Centrais Geradoras Ltda. ("CPFL Centrais Geradoras") |
Limited company |
Direct |
São Paulo |
6 MHPPs |
4 |
4 |
Transmission |
Company Type |
|
Core activity |
|
Equity Interest |
|
CPFL Transmissão Piracicaba S.A. ("CPFL Transmissão Piracicaba") |
Private corporation |
Electric energy transmission services |
Indirect |
|||
CPFL Transmissão Morro Agudo S.A. ("CPFL Transmissão Morro Agudo") |
Private corporation |
|
Electric energy transmission services |
|
Indirect |
|
Notes:
(a) CPFL Geração holds 51.54% of the assured power and power of the Serra da Mesa HPP, whose concession belongs to Furnas. The Cariobinha HPP and the Carioba TPP projects are deactivated pending the position of the Ministry of Mines and Energy on the anticipated closure of its concession and are not included in the table.
(b) The joint venture Chapecoense fully consolidates the interim financial statements of its direct subsidiary, Foz de Chapecó;
(c) Paulista Lajeado has a 7% participation in the installed power of Investco S.A. (5.94% share of its capital);
(d) On December 31, 2017, was approved the merger of the subsidiaries Companhia Luz and Força Santa Cruz, Companhia Leste Paulista de Energia, Companhia Jaguari de Energia, Companhia Sul Paulista de Energia and Companhia Luz e Força de Mococa into Companhia Jaguari de Energia, whose fancy name became "CPFL Santa Cruz.
Página 8 de 59
Energy commercialization |
Company Type |
Core activity |
Equity Interest |
CPFL Comercialização Brasil S.A. ("CPFL Brasil") |
Private corporation |
Energy commercialization |
Direct |
Clion Assessoria e Comercialização de Energia Elétrica Ltda. ("CPFL Meridional") |
Limited company |
Commercialization and provision of energy services |
Indirect |
CPFL Comercialização Cone Sul S.A. ("CPFL Cone Sul") |
Private corporation |
Energy commercialization |
Indirect |
CPFL Planalto Ltda. ("CPFL Planalto") |
Limited company |
Energy commercialization |
Direct |
CPFL Brasil Varejista S.A. ("CPFL Brasil Varejista") |
Private corporation |
Energy commercialization |
Indirect |
Services |
Company Type |
Core activity |
Equity Interest |
CPFL Serviços, Equipamentos, Industria e Comércio S.A. |
Private corporation |
Manufacturing, commercialization, rental and maintenance of electro-mechanical equipment and service provision |
Direct |
NECT Serviços Administrativos Ltda ("Nect") |
Limited company |
Provision of administrative services |
Direct |
CPFL Atende Centro de Contatos e Atendimento Ltda. ("CPFL Atende") |
Limited company |
Provision of telephone answering services |
Direct |
CPFL Total Serviços Administrativos Ltda. ("CPFL Total") |
Limited company |
Billing and collection services |
Direct |
CPFL Eficiência Energética S.A ("CPFL Eficiência") |
Private corporation |
Management in Energy Efficiency |
Direct |
TI Nect Serviços de Informática Ltda. ("Authi") |
Limited company |
IT services |
Direct |
CPFL GD S.A ("CPFL GD") |
Private corporation |
Electric energy generation services |
Indirect |
Others |
Company Type |
Core activity |
Equity Interest |
CPFL Jaguari de Geração de Energia Ltda. ("Jaguari Geração") |
Limited company |
Venture capital company |
Direct |
Chapecoense Geração S.A. ("Chapecoense") |
Private corporation |
Venture capital company |
Indirect |
Sul Geradora Participações S.A. ("Sul Geradora") |
Private corporation |
Venture capital company |
Indirect |
CPFL Telecom S.A. ("CPFL Telecom") |
Private corporation |
Telecommunication services |
Direct |
Página 9 de 59
3.1) Consolidation of CPFL Renováveis Financial Statements
On March 31, 2018, CPFL Energia indirectly held 51.6% of CPFL Renováveis, through its subsidiary CPFL Geração. CPFL Renováveis has been fully consolidated (100%, line by line), in CPFL Energia’s financial statements since August 1, 2011, and the interest held by the non-controlling shareholders has been mentioned bellow the net income line (in the Financial Statements), as “Non-Controlling Shareholders’ Interest”, and in the Shareholders Equity (in the Balance Sheet) in the line with the same name.
3.2) Consolidation of RGE Sul Financial Statements
On March 31, 2018, CPFL Energia held the following stake in the capital stock of RGE Sul: 76.3893%, directly, and 23.4561%, indirectly, through CPFL Brasil. RGE Sul has been fully consolidated (100%, line by line), in CPFL Energia’s financial statements since November 1st, 2016.
3.3) Economic-Financial Performance Presentation
In accordance with U.S. SEC (Securities and Exchange Commission) guidelines and pursuant to items 100(a) and (b) of Regulation G, with the disclosure of 4Q16/2016 results, in order to avoid the disclosure of non-GAAP measures, we no longer disclose the economic-financial performance considering the proportional consolidation of the generation projects and the adjustment of the numbers for non-recurring items, focusing the disclosure in the IFRS criterion. Only in chapter 5, of Indebtedness, we continue presenting the information in the financial covenants criterion, considering that the proper reconciliation with the numbers in the IFRS criterion are presented in item 12.11 of this report.
3.4) Consolidation of Transmission Companies
As of 4Q17, the subsidiaries CPFL Piracicaba and CPFL Morro Agudo are consolidated in the financial statements of the segment "Conventional Generation".
Página 10 de 59
Consolidated Income Statement - CPFL ENERGIA (R$ Million) | |||
|
1Q18 |
1Q17 |
Var. |
Gross Operating Revenue |
9,637 |
8,730 |
10.4% |
Net Operating Revenue |
6,375 |
5,539 |
15.1% |
Cost of Electric Power |
(4,014) |
(3,221) |
24.6% |
Operating Costs & Expenses |
(1,470) |
(1,579) |
-6.9% |
EBIT |
891 |
739 |
20.4% |
EBITDA1 |
1,366 |
1,196 |
14.3% |
Financial Income (Expense) |
(308) |
(436) |
-29.5% |
Income Before Taxes |
668 |
383 |
74.5% |
Net Income |
419 |
232 |
80.7% |
Note: (1) EBITDA is calculated from the sum of net income, taxes, financial result and depreciation/amortization, according to CVM Instruction no. 527/12. See the calculation in item 4.6 of this report.
Income Statement by business segment - CPFL Energia (R$ million) | ||||||||||||||||
|
|
Distribution |
|
Conventional Generation |
|
Renewable Generation |
|
Commerciali-zation |
|
Services |
|
Others |
|
Eliminations |
|
Total |
1Q18 | ||||||||||||||||
Net operating revenue |
5,201 |
281 |
384 |
710 |
112 |
- |
(313) |
6,375 | ||||||||
Operating costs and expenses |
|
(4,408) |
|
(42) |
|
(156) |
|
(702) |
|
(89) |
|
(9) |
|
313 |
|
(5,094) |
Depreciation e amortization |
(181) |
(30) |
(158) |
(1) |
(6) |
(16) |
- |
(390) | ||||||||
Income from electric energy service |
|
612 |
|
210 |
|
70 |
|
7 |
|
17 |
|
(25) |
|
- |
|
891 |
Equity accounting |
- |
85 |
- |
- |
- |
- |
- |
85 | ||||||||
EBITDA |
|
792 |
|
325 |
|
228 |
|
8 |
|
23 |
|
(9) |
|
- |
|
1,366 |
Financial result |
(105) |
(68) |
(129) |
(7) |
(0) |
2 |
- |
(308) | ||||||||
Income (loss) before taxes |
507 |
227 |
(59) |
(0) |
17 |
(23) |
- |
668 | ||||||||
Income tax and social contribution |
(187) |
(45) |
(13) |
(0) |
(4) |
0 |
- |
(249) | ||||||||
Net income (loss) |
|
321 |
|
182 |
|
(73) |
|
(0) |
|
13 |
|
(23) |
|
- |
|
419 |
1Q17 | ||||||||||||||||
Net operating revenue |
4,459 |
299 |
371 |
621 |
101 |
1 |
(313) |
5,539 | ||||||||
Operating costs and expenses |
|
(3,833) |
|
(83) |
|
(134) |
|
(580) |
|
(83) |
|
(21) |
|
313 |
|
(4,423) |
Depreciation e amortization |
(174) |
(30) |
(151) |
(1) |
(4) |
(17) |
- |
(376) | ||||||||
Income from electric energy service |
|
452 |
|
186 |
|
86 |
|
40 |
|
13 |
|
(37) |
|
- |
|
739 |
Equity accounting |
- |
80 |
- |
- |
- |
- |
- |
80 | ||||||||
EBITDA |
|
626 |
|
296 |
|
236 |
|
41 |
|
18 |
|
(20) |
|
- |
|
1,196 |
Financial result |
(181) |
(101) |
(128) |
(11) |
1 |
(16) |
- |
(436) | ||||||||
Income (loss) before taxes |
271 |
165 |
(43) |
28 |
15 |
(53) |
- |
383 | ||||||||
Income tax and social contribution |
(105) |
(28) |
(12) |
(10) |
(4) |
8 |
- |
(151) | ||||||||
Net income (loss) |
|
165 |
|
137 |
|
(55) |
|
19 |
|
11 |
|
(45) |
|
- |
|
232 |
Variation | ||||||||||||||||
Net operating revenue |
16.6% |
-5.9% |
3.4% |
14.4% |
10.5% |
-100.0% |
0.0% |
15.1% | ||||||||
Operating costs and expenses |
|
15.0% |
|
-49.9% |
|
15.8% |
|
21.1% |
|
6.8% |
|
-55.8% |
|
0.0% |
|
15.2% |
Depreciation e amortization |
4.0% |
0.4% |
4.5% |
-32.5% |
24.7% |
-5.4% |
- |
3.7% | ||||||||
Income from electric energy service |
|
35.3% |
|
12.8% |
|
-18.1% |
|
-82.0% |
|
28.8% |
|
-32.3% |
|
- |
|
20.4% |
Equity accounting |
- |
7.1% |
- |
- |
- |
- |
- |
7.1% | ||||||||
EBITDA |
|
26.6% |
|
10.0% |
|
-3.7% |
|
-80.9% |
|
27.8% |
|
-54.2% |
|
- |
|
14.3% |
Financial result |
-42.3% |
-32.8% |
0.8% |
-34.6% |
- |
- |
- |
-29.5% | ||||||||
Income (loss) before taxes |
87.3% |
37.9% |
39.0% |
- |
15.0% |
-55.9% |
- |
74.5% | ||||||||
Income tax and social contribution |
77.1% |
63.7% |
10.4% |
-97.0% |
-1.1% |
-96.5% |
- |
65.0% | ||||||||
Net income (loss) |
|
93.9% |
|
32.7% |
|
32.7% |
|
- |
|
20.9% |
|
-49.0% |
|
- |
|
80.7% |
Note: an analysis of the economic-financial performance by business segment is presented in chapter 11.
Página 11 de 59
In 1Q18, it was accounted the total sectoral financial assets in the amount of R$ 374 million, compared to the total sectoral financial liabilities in the amount of R$ 565 million in 1Q17, a variation of R$ 939 million.
On March 31, 2018, the balance of these sectoral financial assets and liabilities was positive in R$ 596 million, compared to a positive balance of R$ 517 million on December 31, 2017 and a negative balance of R$ 1,525 million on March 31, 2017.
As established by the applicable regulation, any sectoral financial assets or liabilities shall be included in the tariffs of the distributors in their respective annual tariff events.
In 1Q18, gross operating revenue reached R$ 9,637 million, representing an increase of 10.4% (R$ 907 million). Deductions from the gross operating revenue was of R$ 3,263 million in 1Q18, representing an increase of 2.2% (R$ 71 million). Net operating revenue reached R$ 6,375 million in 1Q18, registering an increase of 15.1% (R$ 836 million).
The main factors that affected the net operating revenue were:
· Increase of revenues in the Distribution segment, in the amount of R$ 742 million (for more details, see item 11.1.1.2);
· Increase of revenues in the Commercialization segment, in the amount of R$ 89 million;
· Increase of revenues in the Renewable Generation segment, in the amount of R$ 13 million;
· Increase of revenues in the Services segment, in the amount of R$ 11 million;
Partially offset by:
· Reduction of revenues in the Conventional Generation segment, in the amount of R$ 18 million;
· Reduction of revenues in Others, in the amount of R$ 1 million.
Página 12 de 59
Cost of Electric Energy (R$ Million) | |||
|
1Q18 |
1Q17 |
Var. |
Cost of Electric Power Purchased for Resale |
|||
Energy from Itaipu Binacional |
558 |
558 |
0.1% |
Energy Purchased in the Spot Market/PROINFA |
86 |
71 |
21.1% |
Energy Purchased through Auction in the Regulated Environment and Bilateral Contracts |
2,975 |
2,693 |
10.5% |
PIS and COFINS Tax Credit |
(318) |
(303) |
4.9% |
Total |
3,301 |
3,018 |
9.4% |
|
|
||
Charges for the Use of the Transmission and Distribution System |
|
|
|
Basic Network Charges |
567 |
248 |
128.9% |
Itaipu Transmission Charges |
62 |
15 |
317.6% |
Connection Charges |
32 |
30 |
7.2% |
Charges for the Use of the Distribution System |
10 |
11 |
-15.2% |
System Service Usage Charges - ESS |
47 |
(83) |
- |
Reserve Energy Charges - EER |
66 |
- |
- |
PIS and COFINS Tax Credit |
(72) |
(19) |
274.4% |
Total |
712 |
202 |
252.2% |
|
|
||
Cost of Electric Energy |
4,014 |
3,221 |
24.6% |
In 1Q18, the cost of electric energy, comprising the purchase of electricity for resale and charges for the use of the distribution and transmission system, amounted to R$ 4,014 million, registering an increase of 24.6% (R$ 793 million).
The factors that explain these variations follow below:
· The cost of electric power purchased for resale reached R$ 3,301 million in 1Q18, an increase of 9.4% (R$ 283 million), due to the following factors:
(i) Increase of 10.5% (R$ 282 million) in the cost of energy purchased through auction in the regulated environment and bilateral contracts, due to the increases of 44.1% in the average purchase price (R$ 250.31/MWh in 1Q18 vs. R$ 173.75/MWh in 1Q17), partially offset by the reduction of 23.3% (3,612 GWh) in the volume of purchased energy;
(ii) Increase of 21.1% (R$ 15 million) in the amount of energy purchased in the spot market/PROINFA cost;
(iii) Increase of 0.1% (R$ 0.4 million) in the cost of energy from Itaipu, due to the increase of 6.2% in the average purchase price (R$ 203.86/MWh in 1Q18 vs. R$ 191.89/MWh in 1Q17), partially offset by the reduction of 5.8% (169 GWh) in the volume of purchased energy;
Partially offset by:
(iv) Increase of 4.9% (R$ 15 million) in PIS and COFINS tax credits (cost reducer), generated from the energy purchase.
· Charges for the use of the transmission and distribution system reached R$ 712 million in 1Q18, an increase of 252.2% (R$ 510 million), due to the following factors:
(i) Increase of 128.9% (R$ 320 million) in the basic network charges;
Página 13 de 59
(ii) Variation of R$ 130 million in the System Service Usage Charges – ESS, from a revenue of R$ 83 million in 1Q17 to an expense of R$ 47 million in 1Q18;
(iii) Expense of R$ 66 million in 1Q18, related to Reserve Energy Charges – EER;
(iv) Increase of 317.6% (R$ 47 million) in Itaipu transmission charges;
Partially offset by:
(v) Increase of 274.4% (R$ 53 million) in PIS and COFINS tax credits (cost reducer), generated from the charges.
Operating costs and expenses reached R$ 1,470 million in 1Q18, compared to R$ 1,579 million in 1Q17, a reduction of 6.9% (R$ 108 million).
The factors that explain these variations follow below:
PMSO
Reported PMSO (R$ million) | ||||
|
1Q18 |
1Q17 |
Variation | |
|
R$ MM |
% | ||
Reported PMSO |
|
|
|
|
Personnel |
(338) |
(332) |
(5) |
1.6% |
Material |
(63) |
(55) |
(8) |
13.7% |
Outsourced Services |
(181) |
(185) |
4 |
-2.3% |
Other Operating Costs/Expenses |
(106) |
(186) |
80 |
-43.1% |
Allowance for doubtful accounts |
(26) |
(47) |
20 |
-43.4% |
Legal, judicial and indemnities expenses |
(12) |
(55) |
43 |
-77.7% |
Others |
(67) |
(84) |
17 |
-20.2% |
Total Reported PMSO |
(687) |
(759) |
72 |
-9.4% |
The PMSO item reached R$ 687 million in 1Q18, compared to R$ 759 million in 1Q17, a reduction of 9.4% (R$ 72 million), due to the following factors:
(i) Personnel - increase of 1.6% (R$ 5 million), mainly due to:
ü Collective bargaining agreement – wages and benefits (R$ 11 million);
Partially offset by:
ü Other effects (R$ 6 million);
Página 14 de 59
(ii) Material - increase of 13.7% (R$ 8 million), mainly due to:
ü Increase in the replacement of material to the maintenance of lines and grid (R$ 13 million);
ü Other effects (R$ 4 million);
Partially offset by:
ü Reduction in the fleet maintenance (R$ 9 million);
(iii) Out-sourced services - reduction of 2.3% (R$ 4 million), mainly due to:
ü Reduction in audit and consulting (R$ 7 million);
Partially offset by:
ü Increase in the assets maintenance (R$ 3 million);
(iv) Other operational costs/expenses - reduction of 43.1% (R$ 80 million), mainly due to:
ü Reduction of 77.7% in legal and judicial expenses (R$ 43 million);
ü Reduction of 43.4% in allowance for doubtful account (R$ 20 million);
ü Other effects (R$ 17 million).
Other operating costs and expenses
Other operating costs and expenses reached R$ 783 million in 1Q18, compared to R$ 820 million in 1Q17, registering a reduction of 4.5% (R$ 37 million), due to the following factors:
· Reduction of 10.6% (R$ 44 million) in Costs of Building the Infrastructure item;
· Reduction of 22.0% (R$ 6 million) in Private Pension Fund item, due to the registration of the impacts of the 2018 actuarial report;
· Reduction of 0.8% (R$ 1 million) in Amortization of Intangible of Concession Asset item;
Partially offset by:
· Increase of 4.7% (R$ 14 million) in Depreciation and Amortization item.
In 1Q18, EBITDA reached R$ 1,366 million, compared to R$ 1,196 million in 1Q17, registering an increase of 14.3% (R$ 171 million).
Página 15 de 59
EBITDA is calculated according to CVM Instruction no. 527/12 and showed in the table below:
EBITDA and Net Income conciliation (R$ million) | |||
|
1Q18 |
1Q17 |
Var. |
Net Income |
419 |
232 |
80.7% |
De preciation and Amortization |
390 |
377 |
|
Financial Result |
308 |
436 |
|
Income Tax / Social Contribution |
249 |
151 |
|
EBITDA |
1,366 |
1,196 |
14.3% |
Financial Result (R$ Million) | |||
|
1Q18 |
1Q17 |
Var. |
Revenues |
|||
Income from Financial Investments |
66 |
160 |
-58.6% |
Additions and Late Payment Fines |
70 |
73 |
-5.3% |
Fiscal Credits Update |
3 |
3 |
0.6% |
Judicial Deposits Update |
9 |
13 |
-33.5% |
Monetary and Foreign Exchange Updates |
23 |
30 |
-25.2% |
Discount on Purchase of ICMS Credit |
7 |
3 |
130.4% |
Sectoral Financial Assets Update |
7 |
- |
- |
PIS and COFINS - over Other Financial Revenues |
(12) |
(15) |
-20.4% |
Others |
25 |
13 |
97.7% |
Total |
197 |
281 |
-29.8% |
|
|
||
Expenses |
|
|
|
Debt Charges |
(343) |
(485) |
-29.3% |
Monetary and Foreign Exchange Updates |
(119) |
(184) |
-35.1% |
(-) Capitalized Interest |
6 |
24 |
-74.3% |
Sectoral Financial Liabilities Update |
(5) |
(27) |
-82.8% |
Use of Public Asset |
(4) |
(3) |
12.3% |
Others |
(40) |
(42) |
-3.6% |
Total |
(505) |
(717) |
-29.6% |
|
|
||
Financial Result |
(308) |
(436) |
-29.5% |
In 1Q18, net financial expense was of R$ 308 million, a reduction of 29.5% (R$ 129 million) compared to the net financial expense of R$ 436 million reported in 1Q17.
The items explaining these variations in Financial Result are as follows:
· Financial Revenues: reduction of 29.8% (R$ 84 million), from R$ 281 million in 1Q17 to R$ 197 million in 1Q18, mainly due to the following factors:
(i) Reduction of 58.6% (R$ 94 million) in the income from financial investments, due to the reductions in the CDI interbank rate and in the average balance of investments;
(ii) Reduction of 25.2% (R$ 8 million) in the monetary and foreign exchange updates, due to the reductions: (a) of R$ 8 million with the zero-cost collar derivative1, from a gain of R$ 15 million in 1Q17 to a gain of R$ 7 million in 1Q18; and (b) of R$ 3 million in other monetary and foreign exchange updates; partially offset by the increases: (c) of R$ 3 million in revenues from fines, interest and monetary adjustment relating to installment payments made by consumers; and (d) of R$ 1 million in the update of the balance of tariff subsidies, as determined by ANEEL;
Página 16 de 59
(iii) Reduction of 33.5% (R$ 4 million) in judicial deposits update;
(iv) Reduction of 5.3% (R$ 4 million) in additions and late payment fines;
Partially offset by:
(v) Increase of 97.7% (R$ 12 million) in other financial revenues;
(vi) Variation of R$ 7 million in sectoral financial assets update;
(vii) Increase of 130.4% (R$ 4 million) in discount on the acquisition of ICMS credit;
(viii) Reduction of 20.4% (R$ 3 million) in PIS and COFINS over Other Financial Revenue (revenue reducer).
· Financial Expenses: reduction of 29.6% (R$ 212 million), from R$ 717 million in 1Q17 to R$ 505 million in 1Q18, mainly due to the following factors:
(i) Reduction of 29.3% (R$ 142 million) of debt charges in local currency, due to the reduction in the CDI interbank rate;
(ii) Reduction of 35.1% (R$ 64 million) in the monetary and foreign exchange updates, due to: (a) the reduction of debt charges in foreign currency, with swap to CDI interbank rate (R$ 85 million); partially offset (b) by the effect of Itaipu’s exchange variation (R$ 13 million); and (c) by the mark-to-market negative effect for financial operations under Law 4,131 – non-cash effect (R$ 8 million);
(iii) Reduction of 82.8% (R$ 23 million) in sectoral financial liabilities update;
(iv) Reduction of 3.6% (R$ 1 million) in other financial expenses;
Partially offset by:
(v) Reduction of 74.3% (R$ 18 million) in capitalized interest (expense reducer);
(vi) Increase of 12.3% (R$ 0.4 million) in the financial expenses with the Use of Public Asset (UBP).
Net income was R$ 419 million in 1Q18, registering an increase of 80.7% (R$ 187 million) if compared to the net income of R$ 232 million observed in 1Q17.
1 In 2015, subsidiary CPFL Geração contracted US$ denominated put and call options, involving the same financial institution as counterpart, and which on a combined basis are characterized as an operation usually known as zero-cost collar. The contracting of this operation does not involve any kind of speculation, inasmuch as it is aimed at minimizing any negative impacts on future revenues of the joint venture ENERCAN, which has electric energy sale agreements with annual restatement of part of the tariff based on the variation in the US$. In addition, according to Management’s view, the scenario was favorable for contracting this type of financial instrument, considering the high volatility implicit in dollar options and the fact that there was no initial cost for same.
Página 17 de 59
1) For debt linked to foreign currency (18% of total in 1Q18), swap operations are contracted, aiming the protection of the foreign exchange and the rate linked to the contract.
Página 18 de 59
Net Debt in IFRS
IFRS - R$ Million |
1Q18 |
1Q17 |
Var. % |
Financial Debt (including hedge) |
(20,427) |
(20,866) |
-2.1% |
(+) Available Funds |
3,029 |
4,878 |
-37.9% |
(=) Net Debt |
(17,398) |
(15,988) |
8.8% |
CPFL Energia has always adopted a solid and conservative financial policy. Thus, the Company has used since 2011, a prefunding strategy, in other words, forecasts the cash needs for the next 24 months and anticipates market access on more favorable terms of liquidity and cost. Thus, since the beginning of 2017, CPFL Energia has worked in 2018 and 2019 prefunding.
1) Consider only the principal debt of R$ 20,859 million. In order to reach the value of debt in IFRS, of R$ 21,365 million, it is excluded accrued interests of R$ 311 million of the period and included other adjustments in the amount of R$ 195 million;
2) Short-term (April 2018 – March 2019) = R$ 4,880 million.
The cash position at the end of 1Q18 had a coverage ratio of 0.62x the amortizations of the next 12 months, enough to honor all amortization commitments until the end of 2H18. The average amortization term, calculated by this schedule, is 2.88 years.
Página 19 de 59
1) As of 2Q17, CPFL Energia started to calculate its debt average cost considering the end of the period, to better reflect the variations on interest rates.
Indexation1 After Hedge2 in Financial Covenants Criteria – 1Q17 vs. 1Q18
Página 20 de 59
1) Considering proportional consolidation of CPFL Renováveis, CERAN, BAESA, ENERCAN, Foz do Chapecó and EPASA;
2) For debt linked to foreign currency (20% of total), swap operations are contracted, aiming the protection of the foreign exchange and the rate linked to the contract.
In 1Q18 Proforma Net Debt totaled R$ 15,585 million, an increase of 12.6% compared to net debt position at the end of 1Q17, in the amount of R$ 13,837 million.
Covenant Criteria (*) - R$ Million |
1Q18 |
1Q17 |
Var. |
Financial Debt (including hedge)1 |
(18,241) |
(18,606) |
-2.0% |
(+) Available Funds |
2,656 |
4,768 |
-44.3% |
(=) Net Debt |
(15,585) |
(13,837) |
12.6% |
EBITDA Proforma2 |
4,708 |
4,192 |
12.3% |
Net Debt / EBITDA |
3.31 |
3.30 |
0,3% |
1) Considering proportional consolidation of CPFL Renováveis, CERAN, BAESA, ENERCAN, Foz do Chapecó and EPASA; 2) Proforma EBITDA in the financial covenants criteria: adjusted according to equivalent participation of CPFL Energia in each of its subsidiaries, with the inclusion of regulatory assets and liabilities and the historical EBITDA of newly acquired projects. |
In line with the criteria for calculation of financial covenants of loan agreements with financial institutions, net debt is adjusted according to the equivalent stake of CPFL Energia in each of its subsidiaries. Also, include in the calculation of Proforma EBITDA the effects of historic EBITDA of newly acquired projects. Considering that the Proforma Net Debt totaled R$ 15,585 million and Proforma EBITDA in the last 12 months reached R$ 4,708 million, the ratio Proforma Net Debt / EBITDA at the end of 1Q18 reached 3.31x.
Página 21 de 59
Investments (R$ Million) | |||
Segment |
1Q18 |
1Q17 |
Var. |
Distribution |
366 |
347 |
5.4% |
Generation - Conventional |
1 |
0 |
339.1% |
Generation - Renewable |
44 |
283 |
-84.4% |
Commercialization |
1 |
0 |
567.2% |
Services and Others1 |
13 |
13 |
6.7% |
Subtotal |
426 |
643 |
-33.8% |
Transmission |
0 |
38 |
-99.5% |
Total |
426 |
681 |
-37.4% |
Note: 1) Others – basically refer to assets and transactions that are not related to the listed segments. |
In 1Q18, R$ 426 million were invested, a reduction of 37.4% compared to 1Q17. Investments in transmission, basically related to CPFL Transmissão Morro Agudo, according to IFRIC 12, were recorded as “Financial Assets of Concession” (non-current assets).
We highlight investments made by CPFL Energia in each segment:
(i) Distribution:
a. Expansion and strengthening of the electric system;
b. Electricity system maintenance and improvements;
c. Operational infrastructure;
d. Upgrade of management and operational support systems;
e. Customer help services;
f. Research and development programs.
(ii) Generation:
a. SHPP Boa Vista II.
On November 9, 2017, CPFL Energia’s Board of Directors approved Board of Executive Officers’ proposal for 2018 Annual Budget and 2019/2022 Multiannual Plan for the Company, which was previously discussed by the Budget and Corporate Finance Commission.
Página 22 de 59
Notes:
1) Constant currency;
2) Disregard investments in Special Obligations on Distribution segment (among other items financed by consumers);
3) Conventional + Renewable.
The Company’s Bylaws require the distribution of at least 25% of net income adjusted according to law, as dividends to its shareholders. The proposal for allocation of net income from the fiscal year is shown below:
|
Thousands of R$ |
Net income of the fiscal year - Individual |
1,179,750 |
Realization of comprehensive income |
25,873 |
Prescribed dividend |
3,768 |
Net income base for allocation |
1,209,391 |
Legal reserve |
(58,988) |
Statutory reserve - concession financial asset |
(123,673) |
Statutory reserve - working capital reinforcement |
(746,541) |
Minimum mandatory dividend |
(280,191) |
Página 23 de 59
Minimum Mandatory Dividend (25%)
The Board of Directors proposed the payment of R$ 280 million in dividends to holders of common shares traded on B3 S.A. – Brasil, Bolsa, Balcão (B3). This proposed amount corresponds to R$ 0.275259517 per share, related to the fiscal year of 2017. This proposal was approved by the Annual General Shareholders’ Meeting (AGM) held on April 27, 2018.
CPFL Energia informed its shareholders and the market, through a Notice to Shareholders released on April 27, 2018 that the Annual General Shareholders’ Meeting held on that date approved the declaration of “Dividend” to be imputed to the 2017 mandatory dividends, pursuant to the following instructions:
(i) Value: the amount of dividends to be paid is R$ 280,190,721.14 (two hundred and eighty million, one hundred and ninety thousand, seven hundred and twenty-one reais and fourteen centavos), equivalent to R$ 0.275259517 per common share;
(ii) Ex-dividend: shareholders owning shares on April 27, 2018 are entitled to receive these dividends. Shares were traded ex-dividend on the São Paulo Stock Exchange (B3) and New York Stock Exchange (NYSE) as of April 30, 2018;
(iii) Payment: said dividends will be paid on June 26, 2018.
Statutory Reserve – Working Capital Reinforcement
For this fiscal year, considering the current macro scenario with an incipient economic recovery, and also considering the uncertainties regarding hydrology, the Company’s Management is proposing the allocation of R$ 747 million to the statutory reserve - working capital reinforcement.
8.1) Stock Performance
CPFL Energia is listed on both the B3 (Novo Mercado) and the New York Stock Exchange (NYSE) (ADR Level III), segments with the highest levels of corporate governance.
B3 |
NYSE | ||||||
Date |
CPFE3 (R$) |
IEE |
IBOV |
Date |
CPL (US$) |
DJBr20 |
Dow Jones |
03/31/2018 |
R$ 24.91 |
41,445 |
85,366 |
03/31/2018 |
$ 15.00 |
25,170 |
24,103 |
12/31/2017 |
R$ 19.35 |
39,732 |
76,402 |
12/31/2017 |
$ 11.44 |
22,612 |
24,838 |
03/31/2017 |
R$ 25.77 |
39,971 |
64,984 |
03/31/2017 |
$ 16.39 |
21,073 |
20,663 |
QoQ |
28.7% |
4.3% |
11.7% |
QoQ |
31.1% |
11.3% |
-3.0% |
YoY |
-3.3% |
3.7% |
-23.9% |
YoY |
-8.5% |
19.4% |
-14.3% |
On March 31, 2018 the price shares closed at R$ 24.91 per share on the B3 and US$ 15.00 per ADR on the NYSE, which represented an increase in the quarter of 28.7% and 31.1%, respectively. Considering the last 12 months, the shares depreciated 3.3% on the B3 and the ADR depreciated 8.5% on the NYSE.
The daily trading volume in 1T18 averaged R$ 19.1 million, of which R$ 15.6 million on the B3 and R$ 3.5 million on the NYSE, representing a reduction of 61.3% in relation to 1T17. The number of trades on the B3 decreased by 25.0%.
Página 24 de 59
Note: Considers the sum of the average daily volume on the B3 and NYSE.
The corporate governance model adopted by CPFL Energia and its subsidiaries is based on the principles of transparency, equity, accountability and corporate responsibility.
In 2017, CPFL marked 13 years since being listed on the B3 and the New York Stock Exchange (“NYSE”). With more than 100 years of history in Brazil, the Company’s shares are listed on the Novo Mercado Special Listing Segment of the B3 with Level III ADRs, a special segment for companies that comply with corporate governance best practices. All CPFL shares are common shares, entitling all shareholders the right to vote with 100% Tag Along rights guaranteed in case of sale of shareholding control.
CPFL’s Management is composed of the Board of Directors (“Board”), its decision-making authority, and the Board of Executive Officers, its executive body. The Board is responsible for defining the strategic business direction of the holding company and subsidiaries, and is composed of 7 members (of which 2 independent members), with terms of one year, eligible for reelection.
The Bylaws of the Board establishes the procedures for evaluating the directors, under the leadership of the Chairman, their main duties and rights.
The Board set up three advisory committees (Management Processes, Risks and Sustainability, People Management and Related Parties), which support the Board in its decisions and monitor relevant and strategic themes, such as people and risk management, sustainability, the surveillance of internal audits and analysis of transactions with Parties Related to controlling shareholders and handling of incidents recorded through complaint hotlines and ethical conduct channels.
The Board of Executive Officers is made up of 1 Chief Executive Officer, 1 Deputy Chief of Executive Officer and 7 Vice Presidents, with terms of two years, eligible for reelection, responsible for executing the strategy of CPFL Energia and its subsidiaries as defined by the Board of Directors in line with corporate governance guidelines. To ensure alignment of governance practices, Executive Officers sit on the Boards of Directors of companies that make up the CPFL group and nominate their respective executive officers.
CPFL has a permanent Fiscal Council, made up of 3 members, that also exercises the duties of the Audit Committee, in line with Sarbanes-Oxley law (SOX) rulings applicable to foreign companies listed on U.S. stock exchanges.
Página 25 de 59
The guidelines and documents on corporate governance are available at the Investor Relations website http://www.cpfl.com.br/ir.
CPFL Energia is a holding company that owns stake in other companies. State Grid Corporation of China (SGCC) controls CPFL Energia through its subsidiaries State Grid International Development Co., Ltd, State Grid International Development Limited (SGID), International Grid Holdings Limited, State Grid Brazil Power Participações S.A. (SGBP) and ESC Energia S.A.:
Reference date: 03/31/2018
Notes:
(1) 51.54% stake of the availability of power and energy of Serra da Mesa HPP, regarding the Power Purchase Agreement between CPFL Geração and Furnas;
(2) RGE Sul is held by CPFL Energia (76.3893%) and CPFL Brasil (23.4561%).
Página 26 de 59
Consolidated Income Statement - Distribution (R$ Million) | |||
|
1Q18 |
1Q17 |
Var. |
Gross Operating Revenue |
8,329 |
7,532 |
10.6% |
Net Operating Revenue |
5,201 |
4,459 |
16.6% |
Cost of Electric Power |
(3,451) |
(2,807) |
22.9% |
Operating Costs & Expenses |
(1,138) |
(1,200) |
-5.1% |
EBIT |
612 |
452 |
35.3% |
EBITDA(1) |
792 |
626 |
26.6% |
Financial Income (Expense) |
(105) |
(181) |
-42.3% |
Income Before Taxes |
507 |
271 |
87.3% |
Net Income |
321 |
165 |
93.9% |
Note:
(1) EBITDA (IFRS) is calculated from the sum of net income, taxes, financial result and depreciation/amortization, as CVM Instruction no. 527/12.
In 1Q18, total sectoral financial assets accounted for R$ 374 million, a variation of R$ 939 million if compared to 1Q17, when sectoral financial liabilities amounted to R$ 565 million.
On March 31, 2018, the balance of sectoral financial assets and liabilities was positive in R$ 596 million, compared to a positive balance of R$ 517 million on December 31, 2017 and a negative balance of R$ 1,525 million on March 31, 2017.
As established by the applicable regulation, any sectoral financial assets or liabilities shall be included in the tariffs of the distributors in their respective annual tariff events.
Página 27 de 59
Operating Revenue (R$ Million) | |||
|
1Q18 |
1Q17 |
Var. |
Gross Operating Revenue |
|||
Revenue with Energy Sales (Captive + TUSD) |
6,950 |
6,956 |
-0.1% |
Short-term Electric Energy |
115 |
212 |
-45.9% |
Revenue from Building the Infrastructure of the Concession |
370 |
378 |
-2.1% |
Sectoral Financial Assets and Liabilities |
374 |
(565) |
- |
CDE Resources - Low-income and Other Tariff Subsidies |
377 |
424 |
-11.1% |
Adjustments to the Concession's Financial Asset |
65 |
49 |
32.6% |
Other Revenues and Income |
79 |
78 |
1.8% |
Total |
8,329 |
7,532 |
10.6% |
|
|
||
Deductions from the Gross Operating Revenue |
|
|
|
ICMS Tax |
(1,400) |
(1,446) |
-3.2% |
PIS and COFINS Taxes |
(736) |
(671) |
9.6% |
CDE Sector Charge |
(898) |
(830) |
8.1% |
R&D and Energy Efficiency Program |
(48) |
(40) |
18.4% |
PROINFA |
(35) |
(44) |
-19.7% |
Tariff Flags and Others |
(7) |
(37) |
-80.6% |
Others |
(5) |
(5) |
0.4% |
Total |
(3,129) |
(3,073) |
1.8% |
|
|
||
Net Operating Revenue |
5,201 |
4,459 |
16.6% |
In 1Q18, gross operating revenue amounted to R$ 8,329 million, an increase of 10.6% (R$ 797 million), due to the following factors:
· Variation of R$ 939 million in the Sectoral Financial Assets/Liabilities, from a sectoral financial liability of R$ 565 million in 1Q17 to a sectoral financial asset of R$ 374 million in 1Q18;
· Increase of 32.6% (R$ 16 million) in the adjustments to the Concession´s Financial Asset;
· Increase of 1.8% (R$ 1 million) in Other Revenues and Income;
Partially offset by:
· Reduction of 45.9% (R$ 98 million) in Short-term Electric Energy;
· Reduction of 11.1% (R$ 47 million) in tariff subsidies (CDE resources);
· Reduction of 2.1% (R$ 8 million) in revenue from building the infrastructure of the concession;
· Reduction of 0.1% (R$ 6 million) in the revenue with energy sales (captive + free clients), due to: (i) the negative average tariff adjustment in the distribution companies for the period between 1Q17 and 1Q18 (highlight for the average reductions of 10.50% in CPFL Paulista and 6.43% in RGE Sul, in April 2017); and (ii) the adoption of the green tariff flag in the months of January, February and March 2018, compared to the green tariff flag applied in the months of January and February 2017 and the yellow tariff flag applied in the month of March 2017; partially offset by the increase of 2.9% in the sales volume within the concession area.
Deductions from the gross operating revenue were R$ 3,129 million in 1Q18, representing an increase of 1.8% (R$ 56 million), due to the following factors:
· Increase of 8.1% (R$ 68 million) in the CDE sector charge;
Página 28 de 59
· Increase of 9.6% (R$ 65 million) in PIS and COFINS taxes;
· Increase of 18.4% (R$ 7 million) in the R&D and Energy Efficiency Program;
Partially offset by the following factors:
· Reduction of 3.2% (R$ 46 million) in ICMS tax;
· Reduction of 80.6% (R$ 30 million) in tariff flags approved by the CCEE;
· Reduction of 19.7% (R$ 9 million) in the PROINFA.
Net operating revenue reached R$ 5,201 million in 1Q18, representing an increase of 16.6% (R$ 742 million).
Cost of Electric Energy (R$ Million) | |||
|
1Q18 |
1Q17 |
Var. |
Cost of Electric Power Purchased for Resale |
|||
Energy from Itaipu Binacional |
558 |
558 |
0.1% |
Energy Purchased in the Spot Market/PROINFA |
1,425 |
78 |
1728.6% |
Energy Purchased through Auction in the Regulated Environment and Bilateral Contracts |
1,045 |
2,264 |
-53.8% |
PIS and COFINS Tax Credit |
(265) |
(267) |
-0.7% |
Total |
2,764 |
2,633 |
5.0% |
|
|
||
Charges for the Use of the Transmission and Distribution System |
|
|
|
Basic Network Charges |
549 |
228 |
141.2% |
Itaipu Transmission Charges |
62 |
15 |
317.6% |
Connection Charges |
30 |
27 |
9.1% |
Charges for the Use of the Distribution System |
5 |
6 |
-16.0% |
System Service Usage Charges - ESS |
47 |
(83) |
- |
Reserve Energy Charges - EER |
66 |
- |
- |
PIS and COFINS Tax Credit |
(71) |
(19) |
278.6% |
Total |
687 |
174 |
294.1% |
|
|
||
Cost of Electric Energy |
3,451 |
2,807 |
22.9% |
In 1Q18, the cost of electric energy, comprising the purchase of electricity for resale and charges for the use of the distribution and transmission system, amounted to R$ 3,451 million, representing an increase of 22.9% (R$ 644 million):
· The cost of electric power purchased for resale was R$ 2,764 million in 1Q18, representing an increase of 5.0% (R$ 131 million), due to the following factors:
(i) Increase of 1728.6% (R$ 1,347 million) in the cost of energy purchased in the short term and Proinfa;
(ii) Reduction of 0.7% (R$ 2 million) in PIS and Cofins tax credit (cost reducer), generated from the energy purchase;
(iii) Increase of 0.1% (R$ 0.4 million) in the cost of energy from Itaipu, due to the increase of 6.2% in the average purchase price (R$ 203.86/MWh in 1Q18 vs. R$ 191.89/MWh in 1Q17), partially offset by the reduction of 5.8% (169 GWh) in the volume of purchased energy;
Partially offset by:
Página 29 de 59
(iv) Increase of 53.8% (R$ 1,219 million) in the cost of energy purchased in the regulated environment and bilateral contracts, due to the reductions of 28.9% in the average purchase price (from R$ 190.89/MWh in 1Q17 to R$ 135.80/MWh in 1Q18) and of 35.1% (4,166 GWh) in the volume of purchased energy.
· Charges for the use of the transmission and distribution system reached R$ 687 million in 1Q18, representing an increase of 294.1% (R$ 513 million), due to the following factors:
(i) Increase of 141.2% (R$ 321 million) in charges for basic network;
(ii) Variation of R$ 130 million in the System Service Usage Charges – ESS, from a revenue of R$ 83 million in 1Q17 to an expense of R$ 47 million in 1Q18;
(iii) Expense of R$ 66 million in 1Q18, related to the Energy Reserve Charges – EER;
(iv) Increase of 317.6% (R$ 47 million) in the Itaipu transmission charges;
(v) Increase of 9.1% (R$ 2 million) in connection charges;
Partially offset by:
(vi) Increase of 278.6% (R$ 53 million) in PIS and Cofins tax credit (cost reducer), generated from the charges;
(vii) Reduction of 16.0% (R$ 1 million) in the usage of the distribution system charges.
Operating costs and expenses reached R$ 1,138 million in 1Q18, compared to R$ 1,200 million in 1Q17, a reduction of 5.1% (R$ 62 million).
The factors that explain these variations follow below:
Página 30 de 59
PMSO
Reported PMSO (R$ million) | ||||
|
1Q18 |
1Q17 |
Variation | |
|
R$ MM |
% | ||
Reported PMSO |
|
|
|
|
Personnel |
(224) |
(224) |
(0) |
0.1% |
Material |
(40) |
(39) |
(1) |
2.7% |
Outsourced Services |
(206) |
(194) |
(12) |
6.2% |
Other Operating Costs/Expenses |
(95) |
(162) |
68 |
-41.7% |
Allowance for doubtful accounts |
(26) |
(47) |
21 |
-44.2% |
Legal, judicial and indemnities expenses |
(15) |
(52) |
37 |
-70.6% |
Others |
(53) |
(63) |
10 |
-15.6% |
Total Reported PMSO |
(565) |
(619) |
54 |
-8.8% |
In 1Q18, PMSO reached R$ 565 million, a reduction of 8.8% (R$ 54 million), compared to R$ 619 million in 1Q17.
Personnel – increase of 0.1% (R$ 0.3 million);
Material – increase of 2.7% (R$ 1 million), mainly due to the increase in the replacement of material to the maintenance of lines and grid (R$ 3 million); partially offset by the reduction in the fleet maintenance (R$ 2 million);
Third party services – increase of 6.2% (R$ 12 million), mainly due to the increases in the following items: maintenance services in lines, network and substations (R$ 7 million), tree pruning (R$ 4 million), outsourced services (R$ 4 million), hardware/software maintenance (R$ 3 million) and meter reading and use (R$ 3 million); partially offset by the reductions in other outsourced services (R$ 6 million), Call Center (R$ 2 million) and audit and consulting (R$ 1 million);
Other operating costs/expenses – reduction of 41.7% (R$ 68 million), due to the following factors: legal and judicial expenses (R$ 37 million), allowance for doubtful accounts (R$ 21 million) and other expenses (R$ 10 million).
Other operating costs and expenses
In 1Q18, other operating costs and expenses reached R$ 573 million, compared to R$ 580 million in 1Q17, registering a reduction of 1.3% (R$ 7 million), with the variations below:
(i) Reduction of 2.1% (R$ 8 million) in cost of building the concession´s infrastructure. This item, which reached R$ 370 million in 1Q18, does not affect results, since it has its counterpart in “operating revenue”;
(ii) Reduction of 22.0% (R$ 6 million) in Private Pension Fund item, due to the registration of the impacts of the 2018 actuarial report;
(iii) Reduction of 7.8% (R$ 1 million) in Amortization of Intangible of Concession Asset item;
Partially offset by:
Página 31 de 59
(iv) Increase of 5.1% (R$ 8 million) in Depreciation and Amortization item.
EBITDA totaled R$ 792 million in 1Q18, compared to R$ 626 million in 1Q17, an increase of 26.6% (R$ 167 million).
Conciliation of Net Income and EBITDA (R$ million) | |||
|
1Q18 |
1Q17 |
Var. |
Net income |
321 |
165 |
93.9% |
Depreciation and Amortization |
181 |
174 |
|
Financial Results |
105 |
181 |
|
Income Tax /Social Contribution |
187 |
105 |
|
EBITDA |
792 |
626 |
26.6% |
Financial Result (R$ Million) | |||
|
1Q18 |
1Q17 |
Var. |
Revenues |
|||
Income from Financial Investments |
24 |
79 |
-69.0% |
Additions and Late Payment Fines |
68 |
72 |
-5.2% |
Fiscal Credits Update |
2 |
1 |
67.7% |
Judicial Deposits Update |
9 |
13 |
-33.8% |
Monetary and Foreign Exchange Updates |
18 |
13 |
36.0% |
Discount on Purchase of ICMS Credit |
7 |
3 |
130.4% |
Sectoral Financial Assets Update |
7 |
- |
- |
PIS and COFINS - over Other Financial Revenues |
(9) |
(11) |
-13.8% |
Others |
11 |
7 |
51.6% |
Total |
136 |
177 |
-23.1% |
|
|
||
Expenses |
|
|
|
Debt Charges |
(145) |
(179) |
-19.3% |
Monetary and Foreign Exchange Updates |
(75) |
(129) |
-41.3% |
(-) Capitalized Interest |
4 |
5 |
-19.1% |
Sectoral Financial Liabilities Update |
(5) |
(27) |
-82.8% |
Others |
(20) |
(29) |
-29.7% |
Total |
(241) |
(359) |
-32.8% |
|
|
||
Financial Result |
(105) |
(181) |
-42.3% |
In 1Q18, the net financial result recorded a net financial expense of R$ 105 million, a reduction of 42.3% (R$ 77 million). The items explaining these changes are as follows:
· Financial Revenue: reduction of 23.1% (R$ 41 million), from R$ 177 million in 1Q17 to R$ 136 million in 1Q18, mainly due to the following factors:
Página 32 de 59
(i) Reduction of 69.0% (R$ 54 million) in the income from financial investments, due to the lower average balance of investments and the fall of CDI interbank rate;
(ii) Reduction of 33.8% (R$ 4 million) in adjustments for inflation of escrow deposits;
(iii) Reduction of 5.2% (R$ 4 million) in fiscal credits update;
Partially offset by:
(iv) Variation of R$ 7 million in sectoral financial assets update;
(v) Increase of 36.0% (R$ 5 million) in adjustments for inflation and exchange rate changes, due to the increases: (a) of R$ 3 million in revenues from fines, interest and monetary adjustment relating to installment payments made by consumers; (b) of R$ 1 million in the adjustment of the balance of tariff subsidies, as determined by Aneel; and (c) of R$ 1 million in other adjustments for inflation and exchange rate changes;
(vi) Increase of 130.4% (R$ 4 million) in the discount on purchase of ICMS credit;
(vii) Increase of 51.6% (R$ 4 million) in other financial revenues;
(viii) Reduction of 13.8% (R$ 1 million) in PIS and Cofins on financial revenues (revenue reducer);
(ix) Reduction of 67.7% (R$ 1 million) in late payment interest and fines.
· Financial Expense: reduction of 32.8% (R$ 118 million), from R$ 359 million in 1Q17 to R$ 241 million in 1Q18, mainly due to the following factors:
(i) Reduction of 41.3% (R$ 53 million) in adjustments for inflation and exchange rate changes, due to: (a) the reduction of debt charges in foreign currency, with swap to CDI interbank rate (R$ 77 million); partially offset by (b) other adjustments for inflation and exchange rate changes (R$ 16 million) and (c) the effect of exchange variation in Itaipu invoices (R$ 8 million);
(ii) Reduction of 19.3% (R$ 35 million) in interest on debt in local currency;
(iii) Reduction of 82.8% (R$ 23 million) in the sectoral financial liabilities update;
(iv) Reduction of 29.7% (R$ 9 million) in other financial expenses;
Partially offset by:
(v) Reduction of 19.1% (R$ 1 million) in capitalized interest (expense reducer).
Net Income totaled R$ 321 million in 1Q18, compared to R$ 165 million in 1Q17, an increase of 93.9% (R$ 155 million).
Página 33 de 59
Reference dates
Tariff Process Dates | |
Disco |
Date |
CPFL Santa Cruz |
March 22nd* |
CPFL Paulista |
April 8th |
RGE Sul |
April 19th |
RGE |
June 19th |
CPFL Piratininga |
October 23rd |
Tariff Revision | |||
Distributor |
Periodicity |
Next Revision |
Cycle |
RGE |
Every 5 years |
June 2018 |
4th PTRC |
CPFL Piratininga |
Every 4 years |
October 2019 |
5th PTRC |
CPFL Santa Cruz |
Every 5 years |
March 2021* |
5th PTRC |
CPFL Paulista |
Every 5 years |
April 2022 |
5th PTRC |
RGE Sul |
Every 5 years |
April 2022 |
5th PTRC |
* In the Public Hearing 038/2015, held by Aneel, the revision dates have been changed to March 22. The date previously used for the adjustments of these distributors was February 3.
Annual tariff adjustments occurred in June and October 2017
|
RGE |
CPFL Piratininga |
Ratifying Resolution |
2,252 |
2,314 |
Adjustment |
3.57% |
7.69% |
Parcel A |
2.17% |
6.78% |
Parcel B |
0.20% |
-0.45% |
Financial Components |
1.21% |
1.37% |
Effect on consumer billings |
5.00% |
17.28% |
Date of entry into force |
6/19/2017 |
10/23/2017 |
Página 34 de 59
Annual tariff adjustments occurred in March 2018¹
|
CPFL Santa Cruz |
CPFL Leste Paulista |
CPFL Jaguari |
CPFL Sul Paulista |
CPFL Mococa |
Ratifying Resolution |
2,376 |
2,376 |
2,376 |
2,376 |
2,376 |
Adjustment |
5.71% |
5.71% |
5.71% |
5.71% |
5.71% |
Parcel A |
5.92% |
5.92% |
5.92% |
5.92% |
5.92% |
Parcel B |
-1.51% |
-1.51% |
-1.51% |
-1.51% |
-1.51% |
Financial Components |
1.30% |
1.30% |
1.30% |
1.30% |
1.30% |
Effect on consumer billings |
5.32% |
7.03% |
21.15% |
7.50% |
3.40% |
Date of entry into force |
3/22/2018 |
3/22/2018 |
3/22/2018 |
3/22/2018 |
3/22/2018 |
¹Considering the merger of the concessions in 12/31/2017, the same percentage of adjustment was considered for all the concessions, but the effect on consumer billings is different for each one of the concessions. |
Página 35 de 59
Periodic tariff reviews occurred in 2018
4th Periodic Tariff Review Cycle |
CPFL Paulista |
RGE Sul |
Date |
Apr-18 |
Apr-18 |
Gross Regulatory Asset Base (A) |
9,457 |
3,605 |
Depreciation Rate (B) |
3.72% |
3.87% |
Depreciation Quota (C = A x B) |
352 |
140 |
Net Regulatory Asset Base (D) |
5,193 |
2,389 |
Pre-tax WACC (E) |
12.26% |
12.26% |
Cost of Capital (F = D x E) |
637 |
290 |
Special Obligations (G) |
45 |
5 |
Regulatory EBITDA (H = C + F + G) |
1,033 |
435 |
OPEX = CAOM + CAIMI (I) |
1,245 |
438 |
Parcel B (J = H + I) |
2,278 |
872 |
Productivity Index Parcel B ( K ) |
0.96% |
0.98% |
Quality Incentive Mechanism ( L) |
-0.17% |
-0.71% |
Parcel B with adjusts (M = J * (K - L) |
2,260 |
870 |
Other Revenues (N) |
88 |
19 |
Adjusted Parcel B (O = M - N) |
2,172 |
851 |
Parcel A (P) |
7,785 |
2,653 |
Required Revenue (Q = O + P) |
9,957 |
3,504 |
CPFL Paulista
On April 3, 2018, ANEEL approved the result of the fourth Periodic Tariff Review of distributor CPFL Paulista. The average effect to be perceived by the consumers is 16.90% and details can be found in the table above.
RGE Sul
On April 17, 2018, ANEEL approved the result of the fourth Periodic Tariff Review of distributor RGE Sul. The average effect to be perceived by the consumers was 22.47% and details can be found in the table above.
SAIDI and SAIFI
Below we are presenting the results achieved by the distribution companies with regard to the main indicators that measure the quality and reliability of their supply of electric energy. The SAIDI (System Average Interruption Duration Index) measures the average duration, in hours, of interruption per consumer per year. The SAIFI (System Average Interruption Frequency Index) measures the average number of interruptions per consumer per year.
Página 36 de 59
SAIDI and SAIFI Indicators | ||||||||||||
Distributor |
SAIDI (hours) |
SAIFI (interruptions) | ||||||||||
2014 |
2015 |
2016 |
2017 |
1Q18 |
ANEEL¹ |
2014 |
2015 |
2016 |
2017 |
1Q18 |
ANEEL¹ | |
CPFL Paulista |
6.92 |
7.76 |
7.62 |
7.14 |
6.90 |
7.38 |
4.87 |
4.89 |
5.00 |
4.94 |
4.76 |
6.33 |
CPFL Piratininga |
6.98 |
7.24 |
8.44² |
6.97 |
6.37 |
6.74 |
4.19 |
4.31 |
3.97² |
4.45 |
4.13 |
5.82 |
RGE |
18.77 |
15.98 |
14.44 |
14.16 |
13.74 |
11.48 |
9.14 |
8.33 |
7.56 |
7.74 |
7.09 |
8.50 |
RGE Sul |
17.75 |
19.11 |
19.45 |
15.58 |
15.30 |
10.79 |
8.87 |
8.42 |
9.41 |
7.62 |
7.05 |
8.30 |
CPFL Santa Cruz - Grouping |
|
|
6.13 |
5.80 |
9.17 |
|
|
|
5.04 |
5.26 |
8.00 | |
|
|
|
|
|
|
|
|
|
|
|
|
|
Notes:
1) 2018 Regulatory Agency (ANEEL);
2) In the previous disclosures, we reported a SAIDI of 6.97 and a SAIFI of 3.80 for CPFL Piratininga in 2016. This number excluded the effect of a CTEEP transmission failure during a storm. However, a decision by ANEEL determined that this effect was included in the SAIDI and SAIFI statistics, so that we corrected the values, as shown in the table.
RGE and RGE Sul have plans to improve SAIDI technical indicators. Among the actions, are part of the plan for 2018, Rural, Troncal and Urban pruning, treatment of major primary, secondary and damage recidivism, programming of services for testing and maintenance in substations and transmission lines, carry out termovision and ultrasound inspections in distribution networks, substations and transmission lines. In addition, part of the maintenance plan, improvements and extensions of the existing structure, with the forecast of exchanges of posts, capacity adjustment, modernization of substations, and installation of remote control and control equipment. This plan is part of a continuous improvement that is already under development. In addition to the significant investments being made, the significant reduction of these investments has already been observed.
The SAIFI indicator was kept below regulatory limits in all companies, reflecting the effectiveness of the maintenance performed and the constant investments in improvements and modernization carried out by CPFL.
Losses
Find below the performance of CPFL distribution companies throughout the last quarters:
12M Accumulated Losses1 |
Technical Losses |
Non-Technical Losses |
Total Losses | |||||||||||||||
1Q17 |
2Q17 |
3Q17 |
4Q17 |
1Q18 |
ANEEL2 |
1Q17 |
2Q17 |
3Q17 |
4Q17 |
1Q18 |
ANEEL2 |
1Q17 |
2Q17 |
3Q17 |
4Q17 |
1Q18 |
ANEEL2 | |
CPFL Energia |
6.25% |
6.22% |
6.21% |
6.19% |
6.22% |
6.40% |
2.98% |
2.76% |
2.94% |
2.82% |
2.66% |
1.77% |
9.23% |
8.98% |
9.15% |
9.01% |
8.87% |
8.17% |
CPFL Paulista |
6.02% |
5.90% |
5.82% |
5.84% |
5.76% |
6.32% |
3.64% |
3.54% |
3.71% |
3.47% |
3.18% |
1.98% |
9.66% |
9.45% |
9.53% |
9.31% |
8.93% |
8.30% |
CPFL Piratininga |
5.31% |
5.37% |
5.45% |
5.50% |
5.55% |
5.52% |
2.20% |
2.07% |
2.08% |
1.96% |
2.19% |
1.43% |
7.52% |
7.44% |
7.53% |
7.46% |
7.74% |
6.95% |
RGE |
7.45% |
7.52% |
7.57% |
7.60% |
7.38% |
7.28% |
2.42% |
1.63% |
1.77% |
1.60% |
1.52% |
1.81% |
9.87% |
9.16% |
9.35% |
9.20% |
8.89% |
9.09% |
RGE Sul |
6.70% |
6.66% |
6.74% |
6.44% |
7.19% |
6.74% |
3.02% |
3.02% |
3.51% |
3.83% |
3.25% |
2.15% |
9.72% |
9.68% |
10.25% |
10.28% |
10.44% |
8.90% |
Nova CPFL Santa Cruz |
7.41% |
7.53% |
7.49% |
7.39% |
7.22% |
7.14% |
1.64% |
0.94% |
1.29% |
1.19% |
1.47% |
0.44% |
9.05% |
8.48% |
8.78% |
8.59% |
8.69% |
7.59% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Notes:
1) The figures above were adequate to a better comparison with the regulatory losses trajectory defined by the Regulatory Agency (ANEEL). In CPFL Piratininga, RGE and RGE Sul, high-voltage customers were disregarded;
2) Regulatory targets for losses are defined in the periodic tariff revision (RTP) process. CPFL Paulista, RGE and RGE Sul are on the 3rd PTRC and other distributors are in 4th PTRC.
The consolidated losses index of CPFL Energia was of 8.87% in 1Q18, compared to 9.23% in 1Q17, a decrease of 0.36 p.p.
Página 37 de 59
Find below how was performance of losses in low voltage market:
12M Accumulated Losses - LV1 |
Non-technical Losses / LV | |||||
1Q17 |
2Q17 |
3Q17 |
4Q17 |
1Q18 |
ANEEL2 | |
CPFL Paulista |
8.59% |
8.36% |
8.78% |
8.17% |
7.76% |
5.78% |
CPFL Piratininga |
6.21% |
5.85% |
5.89% |
5.56% |
6.17% |
3.90% |
RGE |
5.99% |
4.03% |
4.36% |
3.99% |
3.47% |
4.41% |
RGE Sul |
7.15% |
7.14% |
8.28% |
9.14% |
7.06% |
4.90% |
Nova CPFL Santa Cruz |
3.61% |
2.07% |
2.85% |
2.62% |
3.10% |
0.96% |
Note: 1) Regulatory targets for losses are defined in the periodic tariff revision (RTP) process. CPFL Paulista, RGE and RGE Sul are on the 3rd PTRC and other distributors are in 4th PTRC. |
Consolidated Income Statement - Commercialization (R$ Million) | |||
|
1Q18 |
1Q17 |
Var. |
Net Operating Revenue |
710 |
621 |
14.4% |
EBITDA(1) |
8 |
41 |
-80.9% |
Net Loss |
(0) |
17 |
- |
Operating Revenue
In 1Q18, net operating revenue reached R$ 710 million, representing an increase of 14.4% (R$ 89 million).
EBITDA
In 1Q18, EBITDA totaled R$ 8 million, compared to R$ 41 million in 1Q17, a reduction of 80.9% (R$ 33 million).
Net Income
In 1Q18, net loss amounted to R$ 0.4 million, compared to a net income of R$ 17 million in 1Q17.
Página 38 de 59
Consolidated Income Statement - Services (R$ Million) | |||
|
1Q18 |
1Q17 |
Var. |
Net Operating Revenue |
112 |
103 |
8.0% |
EBITDA(1) |
23 |
18 |
27.8% |
Net Income |
13 |
11 |
21.3% |
Note: (1) EBITDA is calculated from the sum of net income, taxes, financial result and depreciation/amortization. |
Operating Revenue
In 1Q18, net operating revenue reached R$ 112 million, representing an increase of 8.0% (R$ 9 million).
EBITDA
In 1Q18, EBITDA totaled R$ 23 million, compared to R$ 18 million in 1Q17, an increase of 27.8% (R$ 5 million).
Net Income
In 1Q18, net income amounted to R$ 13 million, compared to R$ 11 million in 1Q17, an increase of 21.3% (R$ 2 million).
Consolidated Income Statement - Conventional Generation (R$ Million) | |||
|
1Q18 |
1Q17 |
Var. |
Gross Operating Revenue |
308 |
326 |
-5.5% |
Net Operating Revenue |
281 |
299 |
-5.9% |
Cost of Electric Power |
(19) |
(22) |
-15.6% |
Operating Costs & Expenses |
(53) |
(91) |
-41.6% |
EBITDA(1) |
325 |
296 |
10.0% |
Net Income |
182 |
137 |
32.7% |
Nota: (1) EBITDA is calculated from the sum of net income, taxes, financial result and depreciation/amortization. |
Página 39 de 59
In the analysis presented in this report we consider the migration of the transmission companies CPFL Piracicaba and CPFL Morro Agudo from “Others” to “Conventional Generation” segment.
In 1Q18, Gross Operating Revenue reached R$ 308 million, a decrease of 5.5% (R$ 18 million) in relation to 1Q17. Net Operating Revenue reached R$ 281 million, registering a decrease of 5.9% (R$ 18 million).
The main factors that affected the net operating revenue are:
Partially offset by:
In the analysis presented in this report we consider the migration of the transmission companies CPFL Piracicaba and CPFL Morro Agudo from “Others” to “Conventional Generation” segment.
In 1Q18, the cost of electric power reached R$ 19 million, a reduction of 15.6% (R$ 3 million), when compared to 1Q17, due mainly to the following factors:
· Reduction of 23.9% (R$ 4 million) in the cost with Electric Energy Purchased for Resale, mainly due to the following factors:
(i) In CPFL Geração, reduction in the cost with the purchase of energy (R$ 8 million), mainly due to the reduction in the average purchase price of the energy from BAESA by 71.2%;
(ii) Reduction of R$ 1 million in the cost with energy from CPFL Centrais Geradoras;
Partially offset by:
(iii) Increase of R$ 4 million in the cost with energy from Paulista Lajeado;
(iv) Increase of R$ 2 million in the energy costs from the plants of Rio das Antas Complex (CERAN), due to the increase in the volume of energy purchased, together with an increase in the average price, as a result of the higher spot price (PLD).
· Increase of 3.8% (R$ 0.3 million) in the cost with Charges for the Use of the Transmission and Distribution System.
Página 40 de 59
In the analysis presented in this report we consider the migration of the transmission companies CPFL Piracicaba and CPFL Morro Agudo from “Others” to “Conventional Generation” segment.
In 1Q18, operating costs and expenses reached R$ 53 million, compared to R$ 91 million in 1Q17, a reduction of 41.6% (R$ 38 million), due to the variations in:
· PMSO item, that reached R$ 23 million in 1Q18, compared to R$ 25 million in 1Q17, registering a reduction of 7.8% (R$ 2 million). The table below shows a summary of the main variations in PMSO:
PMSO (R$ million) | |||
|
1Q18 |
1Q17 |
Variation |
|
% | ||
PMSO |
|
|
|
Personnel |
9 |
10 |
-13.0% |
Material |
1 |
1 |
28.3% |
Outsourced Services |
5 |
5 |
-10.9% |
Other Operating Costs/Expenses |
8 |
9 |
-2.0% |
GSF Risk Premium |
2 |
2 |
1.2% |
Others |
7 |
7 |
-2.9% |
Total PMSO |
23 |
25 |
-7.8% |
The factors that explain these variations follow below:
(i) Reduction of 13.0% (R$ 1 million) in expenses with Personnel;
(ii) Reduction of 10.9% (R$ 1 million) in expenses with Outsourced Services;
(iii) Reduction of 2.0% (R$ 0.2 million) in Other Operating Costs/Expenses;
Partially offset by:
(iv) Increase of 28.3% (R$ 0.2 million) in expenses with Material;
· Other operating costs and expenses reached R $ 31 million in 1Q18, compared to R $ 67 million in 1Q17, a reduction of 45.9% (R $ 36 million), explained by the variations below:
(i) Reduction of R$ 36 million in Costs from Construction of Concession Infrastructure (CPFL Piracicaba and CPFL Morro Agudo);
(ii) Reduction of 24.9% (R$ 0.1 million) in Private Pension Fund;
Partially offset by:
(iii) Increase of 0.4% (R$ 0.1 million) in Depreciation and Amortization.
Página 41 de 59
Equity Income (R$ Million) | ||||
|
1Q18 |
1Q17 |
Var. R$ |
Var. % |
Projects |
||||
Barra Grande HPP |
3 |
1 |
2 |
100.0% |
Campos Novos HPP |
27 |
34 |
(7) |
-19.8% |
Foz do Chapecó HPP |
31 |
25 |
5 |
21.3% |
Epasa TPP |
24 |
19 |
5 |
27.5% |
Total |
85 |
80 |
6 |
7.1% |
In 1Q18, Equity Income result reached R$ 85 million, compared to R$ 80 million in 1Q17, an increase of 7.1% (R$ 6 million).
Equity Income (R$ Million) |
|
|
|
|
EPASA |
1Q18 |
1Q17 |
Var. R$ |
Var. % |
Net Revenue |
69 |
70 |
(1) |
-1.9% |
Operating Costs / Expenses |
(15) |
(14) |
(1) |
6.6% |
Deprec. / Amortization |
(6) |
(7) |
0 |
-2.5% |
Net Financial Result |
0 |
6 |
(5) |
-91.8% |
Income Tax |
(14) |
(18) |
3 |
-19.8% |
Net Income |
27 |
34 |
(7) |
-19.8% |
|
|
|||
Equity Income (R$ Million) |
|
|
|
|
FOZ DO CHAPECO |
1Q18 |
1Q17 |
Var. R$ |
Var. % |
Net Revenue |
16 |
13 |
2 |
17.1% |
Operating Costs / Expenses |
(5) |
(6) |
1 |
-19.7% |
Deprec. / Amortization |
(3) |
(3) |
(0) |
0.5% |
Net Financial Result |
0 |
0 |
(0) |
-34.6% |
Income Tax |
(2) |
(1) |
(1) |
132.5% |
Net Income |
3 |
1 |
2 |
137.8% |
|
|
|||
Equity Income (R$ Million) |
|
|
|
|
BAESA |
1Q18 |
1Q17 |
Var. R$ |
Var. % |
Net Revenue |
106 |
104 |
2 |
2.3% |
Operating Costs / Expenses |
(24) |
(23) |
(1) |
4.9% |
Deprec. / Amortization |
(15) |
(16) |
1 |
-4.3% |
Net Financial Result |
2 |
4 |
(2) |
-55.0% |
Income Tax |
(16) |
(16) |
0 |
-0.2% |
Net Income |
31 |
25 |
5 |
21.3% |
Página 42 de 59
Equity Income (R$ Million) |
|
|
|
|
ENERCAN |
1Q18 |
1Q17 |
Var. R$ |
Var. % |
Net Revenue |
93 |
89 |
4 |
5.0% |
Operating Costs / Expenses |
(58) |
(59) |
1 |
-1.4% |
Deprec. / Amortization |
(5) |
(4) |
(0) |
7.5% |
Net Financial Result |
1 |
1 |
(1) |
-46.1% |
Income Tax |
(5) |
(4) |
(1) |
15.9% |
Net Income |
24 |
19 |
5 |
27.5% |
In 1Q18, EBITDA was of R$ 325 million, compared to R$ 296 million in 1Q17, an increase of 10.0% (R$ 29 million).
Conciliation of Net Income and EBITDA (R$ million) | |||
|
1Q18 |
1Q17 |
Var. |
Net Income |
182 |
137 |
32.7% |
Depreciation and Amortization |
30 |
30 |
|
Financial Result |
68 |
101 |
|
Income Tax /Social Contribution |
45 |
28 |
|
EBITDA |
325 |
296 |
10.0% |
Página 43 de 59
In 1Q18, the financial result was a net expense of R$ 68 million, representing a reduction of 32.8% (R$ 33 million), compared to net financial expenses of R$ 101 million registered in 1Q17.
· Financial Revenues moved from R$ 51 million in 1Q17 to R$ 20 million in 1Q18, a reduction of 59.6% (R$ 31 million), due to:
ü Reduction of 58.5% (R$ 20 million) in income from financial investments;
ü Reduction of R$ 13 million (73.7%) in monetary and foreign exchange updates, due to the effect of the zero-cost collar derivative2, from a gain of R$ 17 million in 1Q17 to a gain of R$ 4 million in 1Q18;
Partially offset by:
ü Reduction of 54.8% (R$ 1 million) in PIS and COFINS over other financial revenue (revenue reducer);
· Financial Expenses moved from R$ 152 million in 1Q17 to R$ 88 million in 1Q18, a reduction of 41.7% (R$ 63 million), due to:
ü Reduction of 44.2% (R$ 51 million) in debt charges, mainly due to the reduction in the CDI interbank rate;
ü Reduction of 37.5% (R$ 12 million) in monetary and foreign exchange updates;
ü Reduction of 59.6% (R$ 1 million) in other financial expenses;
Partially offset by:
ü Increase of 12.3% (R$ 0.4 million) in the financial expenses with the Use of Public Asset (UBP).
In 1Q18, net income was of R$ 182 million, compared to a net income of R$ 137 million in 1Q17, an increase of 32.7% (R$ 45 million).
2 In 2015, subsidiary CPFL Geração contracted US$ denominated put and call options, involving the same financial institution as counterpart, and which on a combined basis are characterized as an operation usually known as zero-cost collar. The contracting of this operation does not involve any kind of speculation, inasmuch as it is aimed at minimizing any negative impacts on future revenues of the joint venture ENERCAN, which has electric energy sale agreements with annual restatement of part of the tariff based on the variation in the US$. In addition, according to Management’s view, the scenario was favorable for contracting this type of financial instrument, considering the high volatility implicit in dollar options and the fact that there was no initial cost for same.
Página 44 de 59
Income Statement - CPFL Renováveis ( R$ Million) | |||
|
1Q18 |
1Q17 |
Var. % |
Gross Operating Revenue |
406 |
391 |
3.6% |
Net Operating Revenue |
384 |
371 |
3.4% |
Cost of Electric Power |
(70) |
(53) |
32.3% |
Operating Costs & Expenses |
(243) |
(232) |
4.7% |
EBIT |
70 |
86 |
-18.1% |
EBITDA (1) |
228 |
236 |
-3.7% |
Financial Income (Expense) |
(129) |
(128) |
0.8% |
Income Before Taxes |
(59) |
(43) |
39.0% |
Net Income |
(73) |
(55) |
32.7% |
Note: |
The variations in results over the years were mainly influenced by the increase in net revenue as a result of the new capacity coming into operation and by the lower energy generation.
Gross Operating Revenue reached R$ 406 million in 1Q18, representing an increase of 3.6% (R$ 15 million).
Net Operating Revenue reached R$ 384 million in 1Q18, representing an increase of 3.4% (R$ 13 million). This increase is mainly due to the following factors:
Wind Source:
(i) Commercial start-up of Pedra Cheirosa wind complex, partially offset by the lower volume of energy generated in the farms of Rio Grande do Norte and Ceará and the lower availability of wind farms in Ceará due to the recovery plan for the wind turbines operated by Suzlon;
(ii) Positive effect of the new energy auction through the Surplus and Deficit Compensation Mechanism (MCSD), since the contract price entered into in the free market was higher than the contract price in the regulated market for the eight wind farms that participated in this auction;
SHPPs Source:
(iii) Positive liquidations at CCEE (secondary) and a contractual price adjustment of the SHPPs partially compensated by hedge and swap operations settled in PLD at Holding that happened in 1T17;
In 1Q18, Cost of Eletric Power was of R$ 70 million, an increase of 32.3% (R$ 17 million) related to 1Q17, mainly due to the necessity to purchase energy to meet the exposure in the spot market and hedge occurred in 1Q18.
Página 45 de 59
In 1Q18, Operating Costs and Expenses reached R$ 243 million, representing an increase of 4.7% (R$ 11 million), due to variations in:
· PMSO item, that reached R$ 85 million in 1Q18, compared to R$ 81 million in 1Q17, registering an increase of 5.1% (R$ 4 million). The table below shows a summary of the main variations in PMSO:
PMSO (R$ million) | ||||
|
1Q18 |
1Q17 |
Variation | |
|
R$ MM |
% | ||
Reported PMSO |
|
|
|
|
Personnel |
(25) |
(23) |
(2) |
9.0% |
Material |
(10) |
(5) |
(5) |
98.6% |
Outsourced Services |
(43) |
(40) |
(2) |
6.1% |
Other Operating Costs/Expenses |
(8) |
(13) |
5 |
(0.4) |
GSF Risk Premium |
(1) |
(1) |
1 |
- |
Others |
(7) |
(12) |
5 |
-38.6% |
Total PMSO |
(85) |
(81) |
(4) |
5.1% |
The factors that explain these variations follow below:
(i) Increase of 9.0% (R$ 2 million) in expenses with Personnel;
(ii) Increase of 98.6% (R$ 5 million) in expenses with Material;
(iii) Increase of 6.1% (R$ 2 million) in expenses with Outsourced Services;
Partially offset by:
(iv) Reduction of 39.7% (R$ 5 million) in Other Operating Costs/Expenses.
· Other operating costs and expenses, are represented by Depreciation and Amortization figures, that reached R$ 158 million in 1Q18, compared to R$ 151 million in 1Q17, registering an increase of 4.5% (R$ 7 million), explained by the portfolio increase due to the start-up of Pedra Cheirosa Wind Complex.
In 1Q18, EBITDA was of R$ 228 million, compared to R$ 236 million in 1Q17, a reduction of 3.7% (R$ 8 million). These results are due to higher costs in energy generation, mainly with energy purchase to attend wind farms exposure in the short term market.
Página 46 de 59
Conciliation of Net Income and EBITDA (R$ million) | |||
|
1Q18 |
1Q17 |
Var. |
Net income |
(73) |
(55) |
32.7% |
Amortization |
158 |
151 |
|
Financial Results |
129 |
128 |
|
Income Tax /Social Contribution |
13 |
12 |
|
EBITDA |
228 |
236 |
-3.7% |
In 1Q18, net Financial Result was an expense of R$ 129 million, aligned with 1T17 result.
The main factors that affected the financial result, not only in the quarter but also in the year, were:
(i) Fall in the CDI Interbank Rate and TJLP;
(ii) The accelerated growth in the Company's assets portfolio is naturally associated with long-term debt, which, as new capacity comes into operation or the acquisitions are consolidated in CPFL Renováveis, increase its financial expenses, affecting its net results. On the other hand, the growth of the portfolio also provides an increase in the generation of operational cash and value for the Companies.
In 1Q18, Net Loss was of R$ 73 million, compared to a Net Loss of R$ 55 million in 1Q17, an increase of 32.7% (R$ 18 million). These results are mainly due to the lower generation in wind farms, increase in expenses with depreciation and amortization and the energy purchase to cover the wind farms exposure in the short term market.
Página 47 de 59
On the date of this report, the portfolio of projects of CPFL Renováveis (100% participation) totaled 2,103 MW of operating installed capacity and 30 MW of capacity under construction. The operational power plants comprises 39 Small Hydroelectric Power Plants – SHPPs (423 MW), 45 wind farms (1,309 MW), 8 biomass thermoelectric power plants (370 MW) and 1 solar power plant (1 MW). Still under construction there is 1 SHPP (30 MW).
Additionally, CPFL Renováveis owns wind, solar and SHPP projects under development totaling 2,574 MW.
The table below illustrates the overall portfolio of assets (100% participation) in operation, construction and development, and its installed capacity on this date.
CPFL Renováveis - Portfolio (100% participation) | |||||
In MW |
SHPP |
Biomass |
Wind |
Solar |
Total |
Operating |
423 |
370 |
1,309 |
1 |
2,103 |
Under construction |
30 |
- |
- |
- |
30 |
Under development |
242 |
- |
1,980 |
352 |
2,574 |
Total |
695 |
370 |
3,289 |
353 |
4,707 |
Boa Vista II SHPP
The Boa Vista II SHPP, project located in the State of Minas Gerais, is scheduled to start operating in 1Q20. The installed capacity is of 29.9 MW and the physical guarantee is of 14.8 average-MW. Energy was sold through a long-term contract in the 2015 A-5 new energy auction (price: R$ 240.47/MWh – March 2018).
Página 48 de 59
(R$ thousands)
Consolidated | |||
ASSETS |
03/31/2018 |
12/31/2017 |
03/31/2017 |
CURRENT |
|||
Cash and Cash Equivalents |
3,028,978 |
3,249,642 |
4,877,813 |
Consumers, Concessionaries and Licensees |
4,258,871 |
4,301,283 |
4,065,465 |
Dividend and Interest on Equity |
56,145 |
56,145 |
75,395 |
Recoverable Taxes |
417,645 |
395,045 |
423,054 |
Derivatives |
341,350 |
444,029 |
197,741 |
Sectoral Financial Assets |
570,967 |
210,834 |
- |
Concession Financial Assets |
24,017 |
23,736 |
10,836 |
Other Credits |
905,061 |
900,498 |
912,246 |
TOTAL CURRENT |
9,603,034 |
9,581,212 |
10,562,550 |
NON-CURRENT |
|||
Consumers, Concessionaries and Licensees |
243,195 |
236,539 |
204,416 |
Affiliates, Subsidiaries and Parent Company |
- |
8,612 |
9,236 |
Judicial Deposits |
854,224 |
839,990 |
769,646 |
Recoverable Taxes |
235,563 |
233,444 |
205,938 |
Sectoral Financial Assets |
66,841 |
355,003 |
- |
Derivatives |
116,934 |
203,901 |
440,011 |
Deferred Taxes |
977,462 |
943,199 |
935,471 |
Concession Financial Assets |
6,794,551 |
6,545,668 |
5,601,969 |
Investments at Cost |
116,654 |
116,654 |
116,654 |
Other Credits |
861,611 |
840,192 |
795,499 |
Investments |
1,065,403 |
1,001,550 |
1,487,245 |
Property, Plant and Equipment |
9,678,537 |
9,787,125 |
9,880,291 |
Intangible |
10,552,350 |
10,589,824 |
10,723,398 |
TOTAL NON-CURRENT |
31,563,326 |
31,701,701 |
31,169,774 |
TOTAL ASSETS |
41,166,359 |
41,282,912 |
41,732,324 |
Página 49 de 59
(R$ thousands)
|
Consolidated | ||
LIABILITIES AND SHAREHOLDERS' EQUITY |
03/31/2018 |
12/31/2017 |
03/31/2017 |
CURRENT |
|||
Suppliers |
2,528,146 |
3,296,870 |
2,232,237 |
Loans and Financing |
3,562,035 |
3,589,607 |
2,940,104 |
Debentures |
1,892,414 |
1,703,073 |
1,444,438 |
Employee Pension Plans |
66,133 |
60,801 |
44,016 |
Regulatory Charges |
145,194 |
581,600 |
339,777 |
Taxes, Fees and Contributions |
721,308 |
710,303 |
785,682 |
Dividend and Interest on Equity |
294,141 |
297,744 |
19,970 |
Accrued Liabilities |
124,533 |
116,080 |
127,680 |
Derivatives |
40,943 |
10,230 |
7,581 |
Sectoral Financial Liabilities |
17,860 |
40,111 |
1,316,071 |
Public Utilities |
10,939 |
10,965 |
10,857 |
Other Accounts Payable |
1,061,146 |
961,306 |
892,000 |
TOTAL CURRENT |
10,464,792 |
11,378,688 |
10,160,412 |
NON-CURRENT |
|||
Suppliers |
130,334 |
128,438 |
130,767 |
Loans and Financing |
6,536,192 |
7,402,450 |
9,366,225 |
Debentures |
8,816,277 |
7,473,454 |
7,579,217 |
Employee Pension Plans |
872,113 |
880,360 |
1,011,715 |
Taxes, Fees and Contributions |
16,459 |
18,839 |
25,096 |
Deferred Taxes |
1,236,496 |
1,249,591 |
1,286,397 |
Reserve for Tax, Civil and Labor Risks |
978,316 |
961,134 |
837,809 |
Derivatives |
37,544 |
84,576 |
165,825 |
Sectoral Financial Liabilities |
23,973 |
8,385 |
209,384 |
Public Utilities |
84,847 |
83,766 |
87,404 |
Other Accounts Payable |
429,795 |
426,889 |
278,850 |
TOTAL NON-CURRENT |
19,162,345 |
18,717,881 |
20,978,689 |
SHAREHOLDERS' EQUITY |
|||
Capital |
5,741,284 |
5,741,284 |
5,741,284 |
Capital Reserve |
468,018 |
468,014 |
468,014 |
Legal Reserve |
798,090 |
798,090 |
739,102 |
Statutory Reserve - Concession Financial Assets |
867,912 |
826,600 |
729,608 |
Statutory Reserve - Strengthening of Working Capital |
1,292,046 |
1,292,046 |
545,505 |
Other Comprehensive Income |
(189,025) |
(164,506) |
(241,043) |
Retained Earnings |
360,478 |
- |
225,616 |
9,338,803 |
8,961,528 |
8,208,086 | |
Non-Controlling Shareholders' Interest |
2,200,419 |
2,224,816 |
2,385,137 |
TOTAL SHAREHOLDERS' EQUITY |
11,539,223 |
11,186,344 |
10,593,224 |
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY |
41,166,359 |
41,282,912 |
41,732,324 |
Página 50 de 59
(R$ thousands)
Consolidated | ||||
|
|
1Q18 |
1Q17 |
Variation |
OPERATING REVENUES |
|
|||
Electricity Sales to Final Customers |
|
6,747,443 |
6,821,851 |
-1.1% |
Electricity Sales to Distributors |
|
998,459 |
950,802 |
5.0% |
Revenue from building the infrastructure |
|
370,562 |
416,039 |
-10.9% |
Update of concession's financial asset |
|
64,857 |
48,923 |
32.6% |
Sectorial financial assets and liabilities |
|
373,547 |
(565,003) |
- |
Other Operating Revenues |
|
1,082,629 |
1,057,772 |
2.3% |
|
9,637,497 |
8,730,385 |
10.4% | |
|
||||
DEDUCTIONS FROM OPERATING REVENUES |
|
(3,262,842) |
(3,191,606) |
2.2% |
NET OPERATING REVENUES |
|
6,374,654 |
5,538,779 |
15.1% |
|
||||
COST OF ELECTRIC ENERGY SERVICES |
|
|||
Electricity Purchased for Resale |
|
(3,301,275) |
(3,018,384) |
9.4% |
Electricity Network Usage Charges |
|
(712,446) |
(202,270) |
252.2% |
|
(4,013,721) |
(3,220,654) |
24.6% | |
OPERATING COSTS AND EXPENSES |
|
|||
Personnel |
|
(337,745) |
(332,483) |
1.6% |
Material |
|
(62,622) |
(55,095) |
13.7% |
Outsourced Services |
|
(180,932) |
(185,253) |
-2.3% |
Other Operating Costs/Expenses |
|
(105,822) |
(185,924) |
-43.1% |
Allowance for Doubtful Accounts |
|
(26,420) |
(46,696) |
-43.4% |
Legal and judicial expenses |
|
(12,284) |
(55,119) |
-77.7% |
Others |
|
(67,118) |
(84,109) |
-20.2% |
Cost of building the infrastructure |
|
(370,559) |
(414,627) |
-10.6% |
Employee Pension Plans |
|
(22,477) |
(28,831) |
-22.0% |
Depreciation and Amortization |
|
(318,676) |
(304,323) |
4.7% |
Amortization of Concession's Intangible |
|
(71,508) |
(72,116) |
-0.8% |
|
(1,470,341) |
(1,578,653) |
-6.9% | |
|
||||
EBITDA1 |
|
1,366,277 |
1,195,765 |
14.3% |
|
||||
INCOME FROM ELECTRIC ENERGY SERVICE |
|
890,592 |
739,472 |
20.4% |
|
||||
FINANCIAL REVENUES (EXPENSES) |
|
|||
Financial Revenues |
|
197,151 |
280,711 |
-29.8% |
Financial Expenses |
|
(504,671) |
(716,850) |
-29.6% |
|
(307,519) |
(436,138) |
-29.5% | |
|
||||
EQUITY ACCOUNTING |
|
|||
Equity Accounting |
|
85,501 |
79,854 |
7.1% |
Assets Surplus Value Amortization |
|
(145) |
(145) |
0.0% |
|
85,356 |
79,709 |
7.1% | |
|
||||
INCOME BEFORE TAXES ON INCOME |
|
668,428 |
383,043 |
74.5% |
|
||||
Social Contribution |
|
(66,869) |
(40,575) |
64.8% |
Income Tax |
(182,156) |
(110,347) |
65.1% | |
|
||||
NET INCOME |
|
419,404 |
232,121 |
80.7% |
Controlling Shareholders' Interest |
|
443,783 |
245,886 |
80.5% |
Non-Controlling Shareholders' Interest |
|
(24,379) |
(13,765) |
77.1% |
Note: (1) EBITDA is calculated from the sum of net income, taxes, financial result and depreciation/amortization, according to CVM Instruction no. 527/12.
Página 51 de 59
(R$ thousands)
Consolidated | ||||
1Q18 |
Last 12M | |||
Beginning Balance |
3,249,642 |
4,877,813 | ||
Net Income Before Taxes |
668,428 |
2,132,055 | ||
Depreciation and Amortization |
390,185 |
1,542,519 | ||
Interest on Debts and Monetary and Foreign Exchange Restatements |
359,359 |
1,629,708 | ||
Consumers, Concessionaries and Licensees |
(62,912) |
(438,033) | ||
Sectoral Financial Assets |
(21,033) |
(466,523) | ||
Accounts Receivable - Resources Provided by the CDE/CCEE |
37,218 |
78,129 | ||
Suppliers |
(768,048) |
277,318 | ||
Sectoral Financial Liabilities |
(55,161) |
(1,707,628) | ||
Accounts Payable - CDE |
(1,356) |
23,733 | ||
Interest on Debts and Debentures Paid |
(327,727) |
(1,716,918) | ||
Income Tax and Social Contribution Paid |
(252,090) |
(438,032) | ||
Others |
(429,933) |
382,338 | ||
(1,131,498) |
(833,389) | |||
Total Operating Activities |
(463,070) |
1,298,666 | ||
Investment Activities |
||||
Acquisition of Property, Plant and Equipment, and Intangibles |
(425,914) |
(2,354,028) | ||
Others |
(19,819) |
76,729 | ||
Total Investment Activities |
(445,733) |
(2,277,299) | ||
Financing Activities |
||||
Loans and Debentures |
2,947,881 |
5,544,228 | ||
Principal Amortization of Loans and Debentures, Net of Derivatives |
(2,256,139) |
(6,152,576) | ||
Dividend and Interest on Equity Paid |
(3,603) |
(116,100) | ||
Others |
- |
(145,753) | ||
Total Financing Activities |
688,139 |
(870,201) | ||
Cash Flow Generation |
(220,664) |
(1,848,834) | ||
Ending Balance - 03/31/2018 |
|
3,028,978 |
|
3,028,978 |
Página 52 de 59
(R$ thousands)
Conventional Generation | |||
|
1Q18 |
1Q17 |
Var. |
OPERATING REVENUE |
|
|
|
Eletricity Sales to Distributors |
285,178 |
279,499 |
2.0% |
Revenue from construction of concession infrastructure |
84 |
37,597 |
-99.8% |
Other Operating Revenues |
22,701 |
8,860 |
156.2% |
|
307,963 |
325,956 |
-5.5% |
|
|
|
|
DEDUCTIONS FROM OPERATING REVENUE |
(26,508) |
(26,740) |
-0.9% |
NET OPERATING REVENUE |
281,455 |
299,216 |
-5.9% |
|
|
|
|
COST OF ELETRIC ENERGY SERVICES |
|
|
|
Eletricity Purchased for Resale |
(11,719) |
(15,394) |
-23.9% |
Eletricity Network Usage Charges |
(6,831) |
(6,578) |
3.8% |
|
(18,550) |
(21,972) |
-15.6% |
OPERATING COSTS AND EXPENSES |
|
|
|
Personnel |
(8,778) |
(10,085) |
-13.0% |
Material |
(683) |
(532) |
28.3% |
Outsourced Services |
(4,852) |
(5,443) |
-10.9% |
Other Operating Costs/Expenses |
(8,463) |
(8,638) |
-2.0% |
Costs of infrastructure construction |
(81) |
(36,185) |
-99.8% |
Employee Pension Plans |
(388) |
(517) |
-24.9% |
Depreciation and Amortization |
(27,655) |
(27,534) |
0.4% |
Amortization of Concession's Intangible |
(2,492) |
(2,491) |
0.0% |
|
(53,392) |
(91,426) |
-41.6% |
|
|
|
|
EBITDA |
325,160 |
295,698 |
10.0% |
|
|
|
|
EBIT |
209,513 |
185,819 |
12.8% |
|
|
|
|
FINANCIAL INCOME (EXPENSE) |
|
|
|
Financial Income |
20,463 |
50,677 |
-59.6% |
Financial Expenses |
(88,328) |
(151,604) |
-41.7% |
|
(67,866) |
(100,926) |
-32.8% |
|
|
|
|
EQUITY ACCOUNTING |
|
|
|
Equity Accounting |
85,501 |
79,854 |
7.1% |
Assets Surplus Value Amortization |
(145) |
(145) |
0.0% |
|
85,356 |
79,709 |
7.1% |
|
|
|
|
INCOME BEFORE TAXES ON INCOME |
227,003 |
164,602 |
37.9% |
|
|
|
|
Social Contribution |
(11,979) |
(7,247) |
65.3% |
Income Tax |
(33,144) |
(20,312) |
63.2% |
|
|||
NET INCOME (LOSS) |
181,880 |
137,043 |
32.7% |
Página 53 de 59
(R$ thousands)
Consolidated (100% Participation) | ||||
|
1Q18 |
1Q17 |
Var. |
Var. % |
OPERATING REVENUES |
| |||
|
5,806 |
23,790 |
(17,983) |
-75.6% |
Eletricity Sales to Distributors |
398,767 |
366,802 |
31,964 |
8.7% |
Other Operating Revenues |
944 |
885 |
58 |
6.6% |
|
405,517 |
391,477 |
14,040 |
3.6% |
|
| |||
DEDUCTIONS FROM OPERATING REVENUES |
(21,964) |
(20,544) |
(1,420) |
6.9% |
NET OPERATING REVENUES |
383,553 |
370,933 |
12,620 |
3.4% |
|
| |||
COST OF ELETRIC ENERGY SERVICES |
| |||
Eletricity Purchased for Resale |
(45,766) |
(28,124) |
(17,642) |
62.7% |
Eletricity Network Usage Charges |
(24,700) |
(25,147) |
447 |
-1.8% |
|
(70,466) |
(53,271) |
(17,194) |
32.3% |
OPERATING COSTS AND EXPENSES |
| |||
Personnel |
(24,961) |
(22,910) |
(2,051) |
9.0% |
Material |
(9,688) |
(4,878) |
(4,810) |
98.6% |
Outsourced Services |
(42,707) |
(40,234) |
(2,473) |
6.1% |
Other Operating Costs/Expenses |
(7,946) |
(13,170) |
5,224 |
-39.7% |
Depreciation and Amortization |
(118,481) |
(112,208) |
(6,273) |
5.6% |
Amortization of Concession's Intangible |
(39,206) |
(38,625) |
(581) |
1.5% |
|
(242,988) |
(232,024) |
(10,964) |
4.7% |
|
|
|
|
|
EBITDA (1) |
227,786 |
236,470 |
(8,684) |
-3.7% |
|
| |||
EBIT |
70,099 |
85,637 |
(15,538) |
-18.1% |
|
| |||
FINANCIAL INCOME (EXPENSE) |
| |||
Financial Income |
30,140 |
38,890 |
(8,750) |
-22.5% |
Financial Expenses |
(159,354) |
(167,044) |
7,690 |
-4.6% |
|
(129,214) |
(128,155) |
(1,059) |
0.8% |
|
| |||
INCOME BEFORE TAXES ON INCOME |
(59,115) |
(42,517) |
(16,597) |
39.0% |
|
| |||
Social Contribution |
(4,618) |
(4,573) |
(45) |
1.0% |
Income Tax |
(8,788) |
(7,573) |
(1,214) |
16.0% |
|
|
|
|
|
NET INCOME |
(72,521) |
(54,664) |
(17,857) |
32.7% |
Note: (1) EBITDA (IFRS) is calculated from the sum of net income, taxes, financial result and depreciation/amortization, as CVM Instruction no. 527/12.
Página 54 de 59
(R$ thousands)
Consolidated | ||||
|
|
1Q18 |
1Q17 |
Variation |
OPERATING REVENUE |
||||
Electricity Sales to Final Customers |
6,281,379 |
6,361,528 |
-1.3% | |
Electricity Sales to Distributors |
202,923 |
285,534 |
-28.9% | |
Revenue from building the infrastructure |
370,478 |
378,442 |
-2.1% | |
Adjustments to the concession´s financial asset |
64,857 |
48,923 |
32.6% | |
Sectoral financial assets and liabilities |
373,547 |
(565,003) |
- | |
Other Operating Revenues |
1,036,257 |
1,022,589 |
1.3% | |
|
8,329,440 |
7,532,014 |
10.6% | |
|
|
|
|
|
DEDUCTIONS FROM OPERATING REVENUE |
(3,128,682) |
(3,072,970) |
1.8% | |
NET OPERATING REVENUE |
5,200,758 |
4,459,044 |
16.6% | |
|
||||
COST OF ELECTRIC ENERGY SERVICES |
||||
Electricity Purchased for Resale |
(2,763,525) |
(2,632,925) |
5.0% | |
Electricity Network Usage Charges |
(687,349) |
(174,396) |
294.1% | |
|
(3,450,874) |
(2,807,321) |
22.9% | |
OPERATING COSTS AND EXPENSES |
|
|||
Personnel |
|
(224,119) |
(223,800) |
0.1% |
Material |
|
(39,840) |
(38,810) |
2.7% |
Outsourced Services |
|
(206,481) |
(194,444) |
6.2% |
Other Operating Costs/Expenses |
|
(94,501) |
(162,068) |
-41.7% |
Allowance for Doubtful Accounts |
|
(26,210) |
(46,977) |
-44.2% |
Legal and Judicial Expenses |
|
(15,395) |
(52,417) |
-70.6% |
Others |
|
(52,896) |
(62,673) |
-15.6% |
Cost of building the infrastructure |
|
(370,478) |
(378,442) |
-2.1% |
Employee Pension Plans |
|
(22,089) |
(28,315) |
-22.0% |
Depreciation and Amortization |
|
(166,372) |
(158,319) |
5.1% |
Amortization of Concession's Intangible |
|
(14,133) |
(15,322) |
-7.8% |
|
(1,138,012) |
(1,199,518) |
-5.1% | |
|
||||
EBITDA (IFRS)(1) |
|
792,377 |
625,845 |
26.6% |
|
||||
EBIT |
|
611,873 |
452,205 |
35.3% |
|
||||
FINANCIAL INCOME (EXPENSE) |
|
|||
Financial Income |
|
136,438 |
177,375 |
-23.1% |
Financial Expenses |
|
(241,145) |
(358,873) |
-32.8% |
Interest on Equity |
|
|||
|
(104,708) |
(181,498) |
-42.3% | |
|
||||
INCOME BEFORE TAXES ON INCOME |
|
507,165 |
270,707 |
87.3% |
|
||||
Social Contribution |
|
(49,883) |
(28,077) |
77.7% |
Income Tax |
|
(136,727) |
(77,273) |
76.9% |
|
||||
Net Income (IFRS) |
|
320,554 |
165,358 |
93.9% |
Note: (1) EBITDA (IFRS) is calculated from the sum of net income, taxes, financial result and depreciation/amortization, as CVM Instruction no. 527/12.
Página 55 de 59
(R$ thousands)
Summary of Income Statement by Distribution Company (R$ Thousands) | |||
CPFL PAULISTA | |||
|
1Q18 |
1Q17 |
Var. |
Gross Operating Revenue |
3,504,262 |
3,206,368 |
9.3% |
Net Operating Revenue |
2,202,574 |
1,892,227 |
16.4% |
Cost of Electric Power |
(1,486,568) |
(1,240,578) |
19.8% |
Operating Costs & Expenses |
(461,701) |
(490,483) |
-5.9% |
EBIT |
254,305 |
161,165 |
57.8% |
EBITDA(1) |
314,362 |
217,374 |
44.6% |
Financial Income (Expense) |
(32,534) |
(72,602) |
-55.2% |
Income Before Taxes |
221,771 |
88,563 |
150.4% |
Net Income |
141,046 |
52,268 |
169.9% |
CPFL PIRATININGA | |||
|
1Q18 |
1Q17 |
Var. |
Gross Operating Revenue |
1,520,521 |
1,415,587 |
7.4% |
Net Operating Revenue |
917,011 |
849,889 |
7.9% |
Cost of Electric Power |
(634,823) |
(576,675) |
10.1% |
Operating Costs & Expenses |
(168,418) |
(190,166) |
-11.4% |
EBIT |
113,769 |
83,049 |
37.0% |
EBITDA(1) |
138,457 |
106,906 |
29.5% |
Financial Income (Expense) |
(24,646) |
(32,505) |
-24.2% |
Income Before Taxes |
89,124 |
50,544 |
76.3% |
Net Income |
56,108 |
31,363 |
78.9% |
RGE | |||
|
1Q18 |
1Q17 |
Var. |
Gross Operating Revenue |
1,458,295 |
1,215,435 |
20.0% |
Net Operating Revenue |
936,187 |
728,517 |
28.5% |
Cost of Electric Power |
(618,201) |
(417,453) |
48.1% |
Operating Costs & Expenses |
(220,033) |
(211,525) |
4.0% |
EBIT |
97,953 |
99,539 |
-1.6% |
EBITDA(1) |
138,511 |
139,124 |
-0.4% |
Financial Income (Expense) |
(21,880) |
(37,486) |
-41.6% |
Income Before Taxes |
76,073 |
62,053 |
22.6% |
Net Income |
48,671 |
39,555 |
23.0% |
RGE SUL | |||
|
1Q18 |
1Q17 |
Var. |
Gross Operating Revenue |
1,459,987 |
1,340,123 |
8.9% |
Net Operating Revenue |
887,639 |
763,188 |
16.3% |
Cost of Electric Power |
(562,388) |
(453,906) |
23.9% |
Operating Costs & Expenses |
(214,818) |
(237,168) |
-9.4% |
EBIT |
110,434 |
72,115 |
53.1% |
EBITDA(1) |
154,727 |
117,477 |
31.7% |
Financial Income (Expense) |
(22,494) |
(27,798) |
-19.1% |
Income Before Taxes |
87,939 |
44,317 |
98.4% |
Net Income |
54,480 |
26,512 |
105.5% |
CPFL SANTA CRUZ | |||
|
1Q18 |
1Q17 |
Var. |
Gross Operating Revenue |
386,375 |
354,500 |
9.0% |
Net Operating Revenue |
257,346 |
225,222 |
14.3% |
Cost of Electric Power |
(148,894) |
(118,709) |
25.4% |
Operating Costs & Expenses |
(73,041) |
(70,176) |
4.1% |
EBIT |
35,411 |
36,337 |
-2.5% |
EBITDA(1) |
46,320 |
44,965 |
3.0% |
Financial Income (Expense) |
(3,154) |
(11,107) |
-71.6% |
Income Before Taxes |
32,257 |
25,231 |
27.9% |
Net Income |
20,249 |
15,661 |
29.3% |
Note:
(1) EBITDA (IFRS) is calculated from the sum of net income, taxes, financial result and depreciation/amortization.
Página 56 de 59
CPFL Paulista | |||
|
1Q18 |
1Q17 |
Var. |
Residential |
2,461 |
2,392 |
2.9% |
Industrial |
2,674 |
2,532 |
5.6% |
Commercial |
1,465 |
1,454 |
0.8% |
Others |
1,050 |
1,026 |
2.3% |
Total |
7,649 |
7,404 |
3.3% |
CPFL Piratininga | |||
|
1Q18 |
1Q17 |
Var. |
Residential |
1,042 |
1,051 |
-0.9% |
Industrial |
1,601 |
1,483 |
7.9% |
Commercial |
652 |
647 |
0.8% |
Others |
291 |
282 |
2.9% |
Total |
3,586 |
3,463 |
3.5% |
RGE | |||
|
1Q18 |
1Q17 |
Var. |
Residential |
694 |
686 |
1.2% |
Industrial |
821 |
792 |
3.7% |
Commercial |
358 |
371 |
-3.7% |
Others |
775 |
758 |
2.3% |
Total |
2,648 |
2,607 |
1.6% |
CPFL Santa Cruz | |||
|
1Q18 |
1Q17 |
Var. |
Residential |
202 |
200 |
1.3% |
Industrial |
237 |
228 |
4.3% |
Commercial |
93 |
94 |
-1.0% |
Others |
166 |
163 |
1.8% |
Total |
699 |
684 |
2.1% |
RGE Sul | |||
|
1Q18 |
1Q17 |
Var. |
Residential |
772 |
800 |
-3.5% |
Industrial |
661 |
629 |
5.2% |
Commercial |
378 |
377 |
0.1% |
Others |
798 |
742 |
7.5% |
Total |
2,609 |
2,549 |
2.4% |
Página 57 de 59
CPFL Paulista | |||
|
1Q18 |
1Q17 |
Var. |
Residential |
2,461 |
2,392 |
2.9% |
Industrial |
641 |
688 |
-6.8% |
Commercial |
1,107 |
1,161 |
-4.7% |
Others |
1,007 |
987 |
2.0% |
Total |
5,215 |
5,227 |
-0.2% |
CPFL Piratininga | |||
|
1Q18 |
1Q17 |
Var. |
Residential |
1,042 |
1,051 |
-0.9% |
Industrial |
287 |
322 |
-10.9% |
Commercial |
477 |
507 |
-5.9% |
Others |
251 |
249 |
0.8% |
Total |
2,056 |
2,129 |
-3.4% |
RGE | |||
|
1Q18 |
1Q17 |
Var. |
Residential |
694 |
686 |
1.2% |
Industrial |
287 |
288 |
-0.3% |
Commercial |
329 |
345 |
-4.6% |
Others |
769 |
754 |
2.0% |
Total |
2,080 |
2,073 |
0.3% |
CPFL Santa Cruz | |||
|
1Q18 |
1Q17 |
Var. |
Residential |
202 |
200 |
1.3% |
Industrial |
98 |
119 |
-17.8% |
Commercial |
87 |
90 |
-3.7% |
Others |
166 |
163 |
1.8% |
Total |
554 |
572 |
-3.3% |
RGE Sul | |||
|
1Q18 |
1Q17 |
Var. |
Residential |
772 |
800 |
-3.5% |
Industrial |
191 |
214 |
-10.4% |
Commercial |
324 |
339 |
-4.5% |
Others |
796 |
741 |
7.4% |
Total |
2,084 |
2,095 |
-0.5% |
Página 58 de 59
(R$ million)
Net Debt Pro forma reconciliation (1Q18) | ||||||||||
Net debt - Generation projects |
||||||||||
Mar-18 |
Majority-controlled subsidiaries |
Investees accounted for under the equity method |
Total | |||||||
CERAN |
CPFL Renováveis |
Lajeado |
Subtotal |
Enercan |
Baesa |
Chapecoense |
Epasa |
Subtotal | ||
Borrowings and debentures |
537 |
6,378 |
- |
6,915 |
640 |
41 |
1,280 |
212 |
2,173 |
9,088 |
(-) Cash and cash equivalents |
(88) |
(907) |
(1) |
(995) |
(70) |
(49) |
(46) |
(51) |
(216) |
(1,210) |
Net Debt |
449 |
5,471 |
- 1 |
5,920 |
570 |
- 7 |
1,233 |
162 |
1,958 |
7,878 |
CPFL stake (%) |
65% |
52% |
59.93% |
- |
48.72% |
25.01% |
51% |
53.34% |
- |
- |
Net Debt in generation projects |
292 |
2,824 |
- 0 |
3,116 |
278 |
- 2 |
629 |
86 |
991 |
4,107 |
Reconciliation |
||||||||||
CPFL Energia |
||||||||||
Gross Debt |
20,427 |
|||||||||
(-) Cash and cash equivalents |
(3,029) |
|||||||||
Net Debt (IFRS) |
17,398 |
|||||||||
(-) Fully consolidated projects |
(5,920) |
|||||||||
(+) Proportional consolidation |
4,107 |
|||||||||
Net Debt (Pro Forma) |
15,585 |
|||||||||
EBITDA Pro Forma reconciliation (1Q18 - LTM ) | ||||||||||
EBITDA - Generation projects |
||||||||||
1Q18 |
Majority-controlled subsidiaries |
Investees accounted for under the equity method |
Total | |||||||
CERAN |
CPFL Renováveis |
Lajeado |
Subtotal |
Enercan |
Baesa |
Chapecoense |
Epasa |
Subtotal | ||
Net operating revenue |
324 |
1,972 |
42 |
2,337 |
578 |
421 |
834 |
798 |
2,631 |
4,968 |
Operating cost and expense |
(106) |
(759) |
(14) |
(878) |
(275) |
(261) |
(189) |
(517) |
(1,242) |
(2,121) |
EBITDA |
218 |
1,213 |
28 |
1,459 |
302 |
160 |
645 |
281 |
1,389 |
2,848 |
CPFL stake (%) |
65% |
51.61% |
59.93% |
- |
48.72% |
25.01% |
51% |
53.34% |
- |
- |
Proportional EBITDA |
142 |
626 |
17 |
784 |
147 |
40 |
329 |
150 |
666 |
1,451 |
Reconciliation |
||||||||||
CPFL Energia - 1Q18 LTM |
||||||||||
Net income |
1,430 |
|||||||||
Amortization |
1,543 |
|||||||||
Financial Results |
1,359 |
|||||||||
Income Tax /Social Contribution |
702 |
|||||||||
EBITDA |
5,034 |
|||||||||
(-) Equity income |
(318) |
|||||||||
(-) EBITDA - Fully consolidated projects |
(1,459) |
|||||||||
(+) Proportional EBITDA |
1,451 |
|||||||||
4,708 |
||||||||||
EBITDA Pro Forma |
4,708 |
|||||||||
Net Debt / EBITDA Pro Forma |
3,31x |
Notes:
1) In accordance with financial covenants calculation in cases of assets acquired by the Company.
Página 59 de 59
CPFL ENERGIA S.A. | ||
|
By: |
/S/ GUSTAVO ESTRELLA
|
Name: Title: |
Gustavo Estrella Chief Financial Officer and Head of Investor Relations |
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 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 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.