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____.
São Paulo, May 11, 2017 – CPFL Energia S.A. (BM&FBOVESPA: CPFE3 and NYSE: CPL), announces its 1Q17 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 1Q16, unless otherwise stated.
CPFL ENERGIA ANNOUNCES ITS 1Q17 RESULTS
Indicators (R$ Million) |
1Q17 |
1Q16 |
Var. |
Sales within the Concession Area - GWh |
16,715 |
14,147 |
18.1% |
Captive Market |
12,103 |
10,568 |
14.5% |
Free Client |
4,611 |
3,579 |
28.8% |
Gross Operating Revenue |
8,730 |
7,586 |
15.1% |
Net Operating Revenue |
5,539 |
4,337 |
27.7% |
EBITDA(1) |
1,196 |
1,035 |
15.6% |
Net Income |
232 |
232 |
-0.1% |
Investments(2) |
681 |
449 |
51.6% |
|
|
|
|
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 Piracicaba and 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.
1Q17 HIGHLIGHTS
• Stable load in the concession area (-0.4%);
• Contracted demand is being preserved: -0.6% Off Peak and -0.2% Peak (Mar-17 x Mar-16);
• Increases of 27.7% in Net Operating Revenue and of 15.6% in EBITDA;
• Investments of R$ 681 million;
• Pro forma net debt of R$ 13.8 billion and leverage of 3.30x pro forma Net Debt/EBITDA;
• CPFL Paulista tariff adjustment, in Apr-17, with an average effect of -10.50% to be perceived by the consumers;
• RGE Sul tariff adjustment, in Apr-17, with an average effect of -6.43% to be perceived by the consumers;
• Current status of State Grid transaction: appraisal report of the Unified Tender Offer in preparation, as approved in the EGM of March 27, 2017;
• Launch of Envo, a company that will offer solutions in distributed solar power generation, manly to residential clients;
• 2016 Annual Report released on April 5, 2017.
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 | 7 |
2.1.3) Free Clients | 7 |
2.2) Contracted Demand (% - high voltage) | 8 |
2.3) Generation Installed Capacity | 8 |
3) INFORMATION ON INTEREST IN COMPANIES AND CRITERIA OF FINANCIAL STATEMENTS | |
CONSOLIDATION | 10 |
3.1) Consolidation of CPFL Renováveis Financial Statements | 12 |
3.2) Consolidation of RGE Sul Financial Statements | 12 |
3.3) Economic-Financial Performance Presentation | 12 |
4) ECONOMIC-FINANCIAL PERFORMANCE | 13 |
4.1) Opening of economic-financial performance by business segment | 13 |
4.2) Reclassification of the Concession Financial Asset | 14 |
4.3) Sectoral Financial Assets and Liabilities | 14 |
4.4) Operating Revenue | 14 |
4.5) Cost of Electric Energy | 14 |
4.6) Operating Costs and Expenses | 15 |
4.7) EBITDA | 18 |
4.8) Financial Result | 18 |
4.9) Net Income | 20 |
5) DEBT | 21 |
5.1) Debt (IFRS) | 21 |
5.2) Debt in Financial Covenants Criteria | 22 |
5.2.1) Debt Amortization Schedule in Financial Covenants Criteria | 22 |
5.2.2) Indexation and Debt Cost in Financial Covenants Criteria | 23 |
5.3) Net Debt in Financial Covenants Criteria and Leverage | 24 |
6) INVESTMENTS | 24 |
6.1) Capital Expenditures | 24 |
6.2) Projected Capital Expenditures | 25 |
7) STOCK MARKETS | 26 |
7.1) Stock Performance | 26 |
7.2) Daily Average Volume | 26 |
8) CORPORATE GOVERNANCE | 27 |
9) SHAREHOLDERS STRUCTURE | 28 |
9.1) Launch of Envo | 28 |
10) PERFORMANCE OF THE BUSINESS SEGMENTS | 30 |
10.1) Distribution Segment | 30 |
10.1.1) Economic-Financial Performance | 30 |
10.1.1.1) Reclassification of the Adjustments to the Concession´s Financial Asset | 30 |
10.1.1.2) Sectoral Financial Assets and Liabilities | 30 |
11.1.1.3) Operating Revenue | 31 |
10.1.1.4) Cost of Electric Power | 32 |
10.1.1.5) Operating Costs and Expenses | 33 |
10.1.1.6) EBITDA | 35 |
10.1.1.7) Financial Result | 35 |
Página 2de 64
10.1.1.8) Net Income | 37 |
10.1.2) Tariff events | 38 |
10.1.3) Operating Performance of Distribution | 39 |
10.2) Commercialization and Services Segments | 41 |
10.2.1) Commercialization Segment | 41 |
10.2.2) Services Segment | 41 |
10.3) Conventional Generation Segment | 42 |
10.3.1) Economic-Financial Performance | 42 |
10.3.1.1) Operating Revenue | 42 |
10.3.1.2) Cost of Electric Power | 42 |
10.3.1.3) Operating Costs and Expenses | 43 |
10.3.1.4) Equity Income | 44 |
10.3.1.5) EBITDA | 45 |
10.3.1.6) Financial Result | 45 |
10.3.1.7) Net Income | 46 |
10.4) CPFL Renováveis | 46 |
10.4.1) Economic-Financial Performance | 46 |
10.4.1.1) Variations in the Income Statement of CPFL Renováveis | 46 |
10.4.1.2) Operating Revenue | 47 |
10.4.1.3) Cost of Electric Power | 47 |
10.4.1.4) Operating Costs and Expenses | 48 |
10.4.1.5) EBITDA | 48 |
10.4.1.6) Financial Result | 49 |
10.4.1.7) Net Income | 49 |
10.4.2) Status of Generation Projects – 100% Participation | 50 |
11) ATTACHMENTS | 51 |
11.1) Statement of Assets – CPFL Energia | 51 |
11.2) Statement of Liabilities – CPFL Energia | 52 |
11.3) Income Statement – CPFL Energia | 53 |
11.4) Cash Flow – CPFL Energia | 54 |
11.5) Income Statement – Conventional Generation Segment | 55 |
11.6) Income Statement – CPFL Renováveis | 56 |
11.7) Income Statement – Distribution Segment | 57 |
11.8) Income Statement – Distribution Segment (without RGE Sul) | 58 |
11.9) Income Statement – Distribution Segment | 59 |
11.10) Sales within the Concession Area by Distributor (In GWh) | 62 |
11.11) Sales to the Captive Market by Distributor (in GWh) | 63 |
11.12) Reconciliation of Net Debt/Ebitda Pro Forma ratio of CPFL Energia for purposes of financial | |
covenants calculation | 64 |
Página 3 de 64
The beginning of 2017 was marked by new prospects and possibilities for the CPFL Group, after the conclusion of the acquisition of the controlling interest in the Company by the Chinese State Grid, the largest global player in the electricity sector. Its long-term strategic vision and technological development will make a great contribution to CPFL’s next steps.
After eight consecutive quarters of decrease, the distribution segment registered stable energy sales in the first quarter of 2017 (+0.1%), disregarding the positive effect of the acquisition of RGE Sul. The residential class registered an increased 1.5%, while industrial and commercial classes fell by 2.2% and 0.7%, respectively, reflecting the effects of the slowdown in economic activity in the country. The acquisition of RGE Sul, consolidated since November 2016, added 2,549 GWh to volumes sold in the first quarter of 2017.
It is also worth mentioning the considerable migration of consumers from the captive market (a 5.3% market reduction) to the free market (+16.1%) during the year 2016. In March 2017, the demand contracted by the high-voltage clients remained practically stable – a reduction of 0.6% during off-peak hours and 0.2% during peak hours, in comparison with the same month of the previous year, which preserves the majority of the remuneration of the business coming from high-voltage clients of this segment.
The group posted EBITDA of R$ 1,196 million in the quarter (+16% vs. 1Q16), reflecting the contribution of the full consolidation of RGE Sul and the improvement in the results from our subsidiary CPFL Renováveis, among other effects. Consolidated leverage of CPFL Energia reached 3.30x net debt/EBITDA at the end of the quarter, in accordance with the criteria used to measure our financial covenants. The decline in interest rates throughout the year will be beneficial for the Company, which has around three-fourths of its debt pegged to the CDI interbank rate.
CPFL maintained its growth strategy at the beginning of 2017. In the renewable energy segment, the company is advancing on construction of the Pedra Cheirosa wind complex, with total installed capacity of 48 MW. In transmission, the Morro Agudo project showed progress in the quarter, reaching 95% progress in the works.
In addition, CPFL founded a new company in early May, Envo, focused on the solar distributed generation market for households, and small commercial clients, thus expanding the portfolio of energy products and services offered by the Group.
Regarding the sale of controlling interest of CPFL Energia, its migration from category A to category B of the Brazilian Securities and Exchange Commission (CVM) and the delisting of its shares from the Novo Mercado segment of the São Paulo Stock Exchange were approved at the Shareholders Meeting held on March 27, 2017. This Unified Tender Offer process requires the preparation of a valuation report, which will be done by the bank Credit Suisse, as approved by minority shareholders at said meeting.
Finally, CPFL’s management remains optimistic about the advances of the Brazilian electricity sector and remains confident in its business platform. For the year 2017, approximately R$ 2.8 billion in investments are projected, and more than R$10 billion in investments are estimated for the next five years, which reinforces the Group’s commitment to its long-term development strategy.
Andre Dorf
CEO of CPFL Energia
Página 4 de 64
Sales within the Concession Area - GWh | |||
|
1Q17 |
1Q16 |
Var. |
Captive Market |
12,103 |
10,568 |
14.5% |
Free Client |
4,611 |
3,579 |
28.8% |
Total |
16,715 |
14,147 |
18.1% |
Sales within the Concession Area (without RGE Sul) - GWh | |||
|
1Q17 |
1Q16 |
Var. |
Captive Market |
10,009 |
10,568 |
-5.3% |
Free Client |
4,157 |
3,579 |
16.1% |
Total |
14,166 |
14,147 |
0.1% |
Note: RGE Sul was consolidated in November 2016. For more information, see item 3.2 of this report.
In 1Q17, sales within the concession area, achieved by the distribution segment, totaled 16,715 GWh, an increase of 18.1%, mainly due to the acquisition of RGE Sul. Disregarding the effect of this acquisition, sales within the concession area would have totaled 14,166 GWh, an increase of 0.1%.
Sales to the captive market totaled 12,103 GWh in 1Q17, an increase of 14.5%, mainly due to the acquisition of RGE Sul; disregarding the effect of this acquisition, sales to the captive market would have totaled 10,009 GWh, a reduction of 5.3%, reflecting mainly the strong client migration to the free market. 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 4,611 GWh in 1Q17, an increase of 28.8%, mainly due to the acquisition of RGE Sul; disregarding the effect of this acquisition, the quantity of energy billed through TUSD would have reached 4,157 GWh, an increase of 16.1%.
Sales within the Concession Area - GWh | ||||
|
1Q17 |
1Q16 |
Var. |
Part. |
Residential |
5,129 |
4,265 |
20.2% |
30.7% |
Industrial |
5,663 |
5,146 |
10.0% |
33.9% |
Commercial |
2,944 |
2,585 |
13.9% |
17.6% |
Others |
2,979 |
2,150 |
38.5% |
17.8% |
Total |
16,715 |
14,147 |
18.1% |
100.0% |
Sales within the Concession Area (without RGE Sul) - GWh | ||||
|
1Q17 |
1Q16 |
Var. |
Part. |
Residential |
4,328 |
4,265 |
1.5% |
30.6% |
Industrial |
5,035 |
5,146 |
-2.2% |
35.5% |
Commercial |
2,566 |
2,585 |
-0.7% |
18.1% |
Others |
2,237 |
2,150 |
4.0% |
15.8% |
Total |
14,166 |
14,147 |
0.1% |
100.0% |
Note: The tables with sales within the concession area by distributor are attached to this report in item 11.10.
Página 5 de 64
Noteworthy in 1Q17, in the concession area:
· Residential class (30.7% of total sales): increase of 20.2%, influenced by the acquisition of RGE Sul. Disregarding the effect of this acquisition, we would have an increase of 1.5%, reflecting the high temperature in 1Q17 in comparison with the 1Q16;
· Commercial class (17.6% of total sales): increase of 13.9%, influenced by the acquisition of RGE Sul. Disregarding the effect of this acquisition, we would have a reduction of 0.7%, still reflecting the low economic activity in comparison with the 1Q16;
· Industrial class (33.9% of total sales): increase of 10.0%, influenced by the acquisition of RGE Sul. Disregarding the effect of this acquisition, we would have a reduction of 2.2%, still reflecting the low economic activity in comparison with the 1Q16. It is noteworthy that a large client of the steel business in the area of CPFL Piratininga has reduced consumption by 50.1% in comparison with the 1Q16; this represents 1.9% of the 2.2% reduction. Therefore, CPFL Piratininga recorded a reduction of 7.3% (117 GWh) in this class (or a reduction of 1.3% disregarding this client). CPFL Paulista recorded a reduction of 0.6% (14 GWh) and RGE had an increase of 3.7% (28 GWh).
Note: in parentheses, the variation in percentage points from 1Q16 to 1Q17.
Página 6 de 64
Sales to the Captive Market - GWh | |||
|
1Q17 |
1Q16 |
Var. |
Residential |
5,129 |
4,265 |
20.2% |
Industrial |
1,631 |
1,849 |
-11.8% |
Commercial |
2,442 |
2,347 |
4.1% |
Others |
2,902 |
2,107 |
37.7% |
Total |
12,103 |
10,568 |
14.5% |
Sales to the Captive Market (without RGE Sul) - GWh | |||
|
1Q17 |
1Q16 |
Var. |
Residential |
4,328 |
4,265 |
1.5% |
Industrial |
1,417 |
1,849 |
-23.4% |
Commercial |
2,103 |
2,347 |
-10.4% |
Others |
2,160 |
2,107 |
2.5% |
Total |
10,009 |
10,568 |
-5.3% |
Note: The tables with captive market sales by distributor are attached to this report in item 11.11.
The increase of 14.5% (1,535 GWh) in sales to the captive market, from 10,568 GWh in 1Q16 to 12,103 GWh in 1Q17, was influenced by the acquisition of RGE Sul. Disregarding the effect of this acquisition, the sales to the captive market would have totaled 10,009 GWh in 1Q17, representing a reduction of 5.3% (559 GWh), mainly due to the performance of the industrial and commercial classes, still reflecting the low economic activity and the migration to the free market, as explained before.
Free Client - GWh | |||
|
1Q17 |
1Q16 |
Var. |
Industrial |
4,032 |
3,297 |
22.3% |
Commercial |
502 |
238 |
110.6% |
Others |
77 |
44 |
77.5% |
Total |
4,611 |
3,579 |
28.8% |
Free Client (without RGE Sul) - GWh | |||
|
1Q17 |
1Q16 |
Var. |
Industrial |
3,618 |
3,297 |
9.7% |
Commercial |
463 |
238 |
94.5% |
Others |
77 |
44 |
75.4% |
Total |
4,157 |
3,579 |
16.1% |
Página 7 de 64
Free Client by Distributor - GWh | |||
|
1Q17 |
1Q16 |
Var. |
CPFL Paulista |
2,177 |
1,845 |
18.0% |
CPFL Piratininga |
1,335 |
1,219 |
9.5% |
RGE |
534 |
432 |
23.5% |
CPFL Santa Cruz |
28 |
12 |
130.8% |
CPFL Jaguari |
42 |
27 |
57.2% |
CPFL Mococa |
7 |
7 |
-7.2% |
CPFL Leste Paulista |
14 |
14 |
4.7% |
CPFL Sul Paulista |
20 |
23 |
-10.9% |
RGE Sul (*) |
454 |
- |
- |
Total |
4,611 |
3,579 |
28.8% |
Note: (*) Considers the quantity of energy billed through the TUSD from 1Q17.
Contracted Demand Evolution | % compared to the same month of the previous year
2.3) Generation Installed Capacity
In 1Q17, the installed capacity of generation of CPFL Energia, considering the proportional stake in each project, reached 3,258 MW, representing an expansion of 4.2% compared to 1Q16. This increase is due to the commercial start-up of Mata Velha SHPP and Campo do Ventos and São Benedito Wind Complexes.
Generation Installed Capacity | MW
Página 8 de 64
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, 2017 and 2016, 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 of São Paulo |
234 |
4,324 |
30 years |
November 2027 |
Companhia Piratininga de Força e Luz ("CPFL Piratininga") |
Publicly-quoted corporation |
Direct |
Interior and coast of São Paulo |
27 |
1,702 |
30 years |
October 2028 |
Rio Grande Energia S.A. ("RGE") |
Publicly-quoted corporation |
Direct |
Interior of Rio Grande do Sul |
255 |
1,466 |
30 years |
November 2027 |
RGE Sul Distribuidora de Energia S.A. ("RGE Sul") |
Publicly-quoted corporation |
Indirect |
Interior of Rio Grande do Sul |
118 |
1,324 |
30 years |
November 2027 |
Companhia Luz e Força Santa Cruz ("CPFL Santa Cruz") |
Private corporation |
Direct |
Interior of São Paulo and Paraná |
27 |
210 |
30 years |
July 2045 |
Companhia Leste Paulista de Energia ("CPFL Leste Paulista") |
Private corporation |
Direct |
Interior of São Paulo |
7 |
58 |
30 years |
July 2045 |
Companhia Jaguari de Energia ("CPFL Jaguari") |
Private corporation |
Direct |
Interior of São Paulo |
2 |
41 |
30 years |
July 2045 |
Companhia Sul Paulista de Energia ("CPFL Sul Paulista") |
Private corporation |
Direct |
Interior of São Paulo |
5 |
85 |
30 years |
July 2045 |
Companhia Luz e Força de Mococa ("CPFL Mococa") |
Private corporation |
Direct |
Interior of São Paulo and Minas Gerais |
4 |
47 |
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 100% |
São Paulo and Goiás |
1 Hydroelectric, 3 SHPPs (a) |
1,295 |
678 |
CERAN - Companhia Energética Rio das Antas ("CERAN") |
Private corporation |
Indirect 65% |
Rio Grande do Sul |
3 Hydroelectric |
360 |
234 |
Foz do Chapecó Energia S.A. ("Foz do Chapecó") (b) |
Private corporation |
Indirect 51% |
Santa Catarina and Rio Grande do Sul |
1 Hydroelectric |
855 |
436 |
Campos Novos Energia S.A. ("ENERCAN") |
Private corporation |
Indirect 48.72% |
Santa Catarina |
1 Hydroelectric |
880 |
429 |
BAESA - Energética Barra Grande S.A. ("BAESA") |
Publicly-quoted corporation |
Indirect 25.01% |
Santa Catarina and Rio Grande do Sul |
1 Hydroelectric |
690 |
173 |
Centrais Elétricas da Paraíba S.A. ("EPASA") |
Private corporation |
Indirect 53.34% |
Paraíba |
2 Thermals |
342 |
182 |
Paulista Lajeado Energia S.A. ("Paulista Lajeado") |
Private corporation |
Indirect 59.93% (c) |
Tocantins |
1 Hydroelectric |
903 |
63 |
CPFL Energias Renováveis S.A. ("CPFL Renováveis") |
Publicly-quoted corporation |
Indirect 51.61% |
See chapter 10.4.2 |
See chapter 10.4.2 |
See chapter 10.4.2 |
See chapter 10.4.2 |
CPFL Centrais Geradoras Ltda. ("CPFL Centrais Geradoras") |
Limited company |
Direct 100% |
São Paulo |
6 MHPPs (d) |
4 |
4 |
Notes:
(a) SHPP – Small Hydroelectric Power Plant;
(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) MHPP – Micro Hydroelectric Power Plant;
Página 10 de 64
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. ("CPFL Serviços") |
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 ESCO") |
Private corporation |
Management in Energy Efficiency |
Direct |
TI Nect Serviços de Informática Ltda. ("Authi") (e) |
Limited company |
IT services |
Direct |
CPFL GD S.A. ("CPFL GD") (f) |
Private corporation |
Electric energy generation services |
Indirect |
(e) In September, 2014 the direct subsidiary TI Nect Serviços de Informática Ltda. (“Authi”), was set up with the objective of providing informatics, information technology maintenance, system update, program development and customization and computer and peripheral equipment maintenance services;
(f) The main objective of CPFL GD S.A., incorporated in August 2015 and fully controlled by CPFL Eficiência Energética S.A., is the provision of general consultancy services in the electric energy market and commercialization of assets related to the electric energy generation plants;
Página 11 de 64
Others |
Company Type |
Core activity |
Equity Interest |
CPFL Jaguariúna Participações Ltda. ("CPFL Jaguariúna") |
Limited company |
Venture capital company |
Direct |
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 |
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") (g) |
Private corporation |
Electric energy transmission services |
Indirect |
(g) The incorporation of CPFL Transmissora Morro Agudo S.A., subsidiary of CPFL Geração, was approved in January 2015, with the objective of building and operating electric energy transmission concessions, including construction, implementation, operation and maintenance of transmission facilities of the basic network of the Interlinked National System (“SIN”).
3.1) Consolidation of CPFL Renováveis Financial Statements
On March 31, 2017, CPFL Energia indirectly held 51.61% 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, 2017, CPFL Energia indirectly held 100% of RGE Sul, through its subsidiary CPFL Jaguariúna. RGE Sul has been fully consolidated (100%, line by line), in CPFL Energia’s financial statements since November 1st, 2016.
In the analysis presented in this report, we consider the impact of the inclusion of RGE Sul as an isolated item.
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 11.12 of this report.
Página 12 de 64
Consolidated Income Statement - CPFL ENERGIA (R$ Million) | |||
|
1Q17 |
1Q16 |
Var. |
Gross Operating Revenue |
8,730 |
7,586 |
15.1% |
Net Operating Revenue |
5,539 |
4,337 |
27.7% |
Cost of Electric Power |
(3,221) |
(2,528) |
27.4% |
Operating Costs & Expenses |
(1,579) |
(1,146) |
37.8% |
EBIT |
739 |
663 |
11.5% |
EBITDA1 |
1,196 |
1,035 |
15.6% |
Financial Income (Expense) |
(436) |
(319) |
36.7% |
Income Before Taxes |
383 |
408 |
-6.0% |
Net Income |
232 |
232 |
-0.1% |
Note: (1) EBITDA is calculated from the sum of net income, taxes, financial result and depreciation/amortization, according to CVM Instruction no. 527/12. 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 |
1Q17 | ||||||||||||||||
Net operating revenue |
4,462 |
257 |
387 |
621 |
103 |
43 |
(335) |
5,539 | ||||||||
Operating costs and expenses |
|
(3,837) |
|
(47) |
|
(151) |
|
(580) |
|
(86) |
|
(58) |
|
335 |
|
(4,423) |
Depreciation e amortization |
(189) |
(31) |
(151) |
(1) |
(4) |
(1) |
- |
(376) | ||||||||
Income from electric energy service |
|
437 |
|
179 |
|
86 |
|
40 |
|
13 |
|
(15) |
|
- |
|
739 |
Equity accounting |
- |
80 |
- |
- |
- |
- |
- |
80 | ||||||||
EBITDA |
|
626 |
|
290 |
|
236 |
|
41 |
|
18 |
|
(15) |
|
- |
|
1,196 |
Financial result |
(182) |
(100) |
(124) |
(13) |
1 |
(19) |
- |
(436) | ||||||||
Income (loss) before taxes |
256 |
159 |
(38) |
27 |
15 |
(35) |
- |
383 | ||||||||
Income tax and social contribution |
(105) |
(27) |
(12) |
(10) |
(4) |
7 |
- |
(151) | ||||||||
Net income (loss) |
|
150 |
|
132 |
|
(50) |
|
17 |
|
11 |
|
(27) |
|
- |
|
232 |
1Q16 (Resubmitted) | ||||||||||||||||
Net operating revenue |
3,527 |
237 |
291 |
432 |
85 |
9 |
(243) |
4,337 | ||||||||
Operating costs and expenses |
|
(2,936) |
|
(51) |
|
(123) |
|
(415) |
|
(68) |
|
(16) |
|
243 |
|
(3,366) |
Depreciation e amortization |
(139) |
(31) |
(133) |
(1) |
(3) |
(1) |
- |
(308) | ||||||||
Income from electric energy service |
|
452 |
|
155 |
|
34 |
|
16 |
|
14 |
|
(8) |
|
- |
|
663 |
Equity accounting |
- |
63 |
- |
- |
- |
- |
- |
63 | ||||||||
EBITDA |
|
591 |
|
249 |
|
168 |
|
17 |
|
18 |
|
(7) |
|
- |
|
1,035 |
Financial result |
(91) |
(84) |
(134) |
4 |
1 |
(15) |
- |
(319) | ||||||||
Income (loss) before taxes |
361 |
134 |
(100) |
19 |
15 |
(23) |
- |
408 | ||||||||
Income tax and social contribution |
(139) |
(25) |
(7) |
(6) |
(5) |
6 |
- |
(175) | ||||||||
Net income (loss) |
|
222 |
|
110 |
|
(107) |
|
14 |
|
10 |
|
(16) |
|
- |
|
232 |
Variation | ||||||||||||||||
Net operating revenue |
26.5% |
8.6% |
33.2% |
43.8% |
21.0% |
404.4% |
37.7% |
27.7% | ||||||||
Operating costs and expenses |
|
30.7% |
|
-8.2% |
|
22.6% |
|
39.8% |
|
26.2% |
|
268.7% |
|
37.7% |
|
31.4% |
Depreciation e amortization |
35.7% |
-0.4% |
13.2% |
-6.4% |
45.5% |
13.3% |
- |
22.2% | ||||||||
Income from electric energy service |
|
-3.2% |
|
16.0% |
|
148.8% |
|
150.9% |
|
-8.5% |
|
95.2% |
|
- |
|
11.5% |
Equity accounting |
- |
25.6% |
- |
- |
- |
- |
- |
25.6% | ||||||||
EBITDA |
|
5.9% |
|
16.4% |
|
41.0% |
|
141.8% |
|
0.8% |
|
104.9% |
|
- |
|
15.6% |
Financial result |
99.6% |
19.5% |
-7.8% |
- |
75.6% |
30.9% |
- |
36.7% | ||||||||
Income (loss) before taxes |
-29.2% |
18.3% |
-61.9% |
36.9% |
-4.3% |
53.5% |
- |
-6.0% | ||||||||
Income tax and social contribution |
-24.1% |
10.4% |
68.2% |
68.9% |
-18.9% |
22.2% |
- |
-13.8% | ||||||||
Net income (loss) |
|
-32.3% |
|
20.1% |
|
-53.1% |
|
23.5% |
|
2.5% |
|
65.1% |
|
- |
|
-0.1% |
Note: an analysis of the economic-financial performance by business segment is presented in chapter 10.
Página 13 de 64
The Company and its electric energy distribution subsidiaries, aiming at the better presentation of their operational and financial performance, concluded that the adjustment of expectation of the cash flow of the indemnable financial asset of the concession of each distributor, originally presented under financial revenue item, in financial result, should be more adequately classified in the operating revenues group, together with other revenues related to its activity. This allocation reflects more accurately the business model of electric energy distribution and provides a better presentation regarding its performance.
Pursuant to CPC 23 / IAS 8 - Accounting Policies, Changes in Estimates and Error Rectification, the CPFL Energia and its Subsidiaries changed their accounting policy previously adopted by an accounting policy that better reflects the performance of the Company's and its subsidiaries' businesses and, therefore, reclassified retrospectively into their income statements for 1Q16.
In 1Q17, it was accounted the total sectoral financial liabilities in the amount of R$ 565 million, compared to the total sectoral financial liabilities in the amount of R$ 732 million in 1Q16, a reduction of 22.8% (R$ 167 million).
On March 31, 2017, the balance of these sectoral financial assets and liabilities was negative in R$ 1,525 million, compared to a negative balance of R$ 915 million on December 31, 2016 and a positive balance of R$ 707 million on March 31, 2016.
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 4Q16, gross operating revenue reached R$ 8,730 million, representing an increase of 15.1% (R$ 1,145 million). Deductions from the gross operating revenue was of R$ 3,192 million in 1Q17, representing a reduction of 1.8% (R$ 57 million). Net operating revenue reached R$ 5,539 million in 1Q17, registering an increase of 27.7% (R$ 1,202 million).
The main factors that affected the net operating revenue were:
· Increase of revenues in the Distribution segment, in the amount of R$ 935 million, mainly due to the acquisition of RGE Sul (for more details, see item 10.1.1.2);
· Increase of revenues in the Commercialization segment, in the amount of R$ 189 million;
· Increase of revenues in CPFL Renováveis, in the amount of R$ 97 million;
· Increase of revenues in Others, in the amount of R$ 35 million;
· Increase of revenues in the Conventional Generation segment, in the amount of R$ 20 million;
· Increase of revenues in the Services segment, in the amount of R$ 18 million;
Partially offset by:
· Reduction of R$ 92 million, due to the eliminations.
In the analysis presented in this report, we consider the impact of the inclusion of RGE Sul as an isolated item.
Página 14 de 64
In 1Q17, 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$ 3,221 million, registering an increase of 27.4% (R$ 693 million).
The factors that explain these variations follow below:
· The cost of electric power purchased for resale reached R$ 3,018 million in 1Q17, an increase of 39.4% (R$ 852 million), due to the following factors:
(i) Impact of the inclusion of RGE Sul in our consolidation in 1Q17. The total cost of electric power purchased for resale in relation to RGE Sul (which was not included in our consolidation in 1Q16) totaled R$ 419 million for 1Q17;
(ii) Increase of 27.1% (R$ 496 million) in the cost of energy purchased through auction in the regulated environment and bilateral contracts, due to the increases of 10.8% in the average purchase price (R$ 170.98/MWh in 1Q17 vs. R$ 154.37/MWh in 1Q16) and of 14.8% (1,750 GWh) in the volume of purchased energy;
(iii) Increase in the amount of energy purchased in the spot market/PROINFA cost (R$ 63 million);
Partially offset by:
(iv) Reduction of 15.2% (R$ 83 million) in the cost of energy from Itaipu, due to the reductions of 11.9% in the average purchase price (R$ 191.38/MWh in 1Q17 vs. R$ 217.28/MWh in 1Q16) and of 3.8% (94 GWh) in the volume of purchased energy;
(v) Increase of 19.3% (R$ 42 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$ 202 million in 1Q17, a reduction of 44.1% (R$ 160 million), due to the following factors:
(i) Variation of R$ 198 million in the System Service Usage Charges – ESS, from an expense of R$ 127 million in 1Q16 to a revenue of R$ 71 million in 1Q17;
(ii) Variation of R$ 31 million in Reserve Energy Charges – EER, since there was no registration of this charge in 1Q17 and there was a revenue of financial resources derived from the Reserve Energy Account (CONER) in the amount of R$ 31 million in 1Q16;
Partially offset by:
(iii) Impact of the inclusion of RGE Sul in our consolidation in 1Q17. The total charges for the use of the transmission and distribution system in relation to RGE Sul (which was not included in our consolidation in 1Q16) totaled R$ 38 million for 1Q17;
(iv) Increase of R$ 10 million in the basic network, connection and usage of the distribution system charges;
(v) Reduction of 59.4% (R$ 21 million) in PIS and COFINS tax credits (cost reducer), generated from the charges.
For this report, we regarded the impact of RGE Sul as an isolated item.
Operating costs and expenses were R$ 1,579 million in 1Q17, an increase of 37.8% (R$ 433 million) if compared to 1Q16 that reached R$ 1,146 million, due to the following factors:
Página 15 de 64
PMSO
PMSO item, that reached R$ 759 million in 1Q17, compared to R$ 607 million in 1Q16, an increase of 25.1% (R$ 152 million).
(i) Personnel - increase of 35.7% (R$ 88 million), mainly due to:
ü RGE Sul acquisition (R$ 41 million);
ü Collective bargaining agreement – wages and benefits (R$ 18 million);
Página 16 de 64
ü Increase in the Services segment business, due to business expansion of CPFL Serviços, CPFL Atende, Nect and CPFL Eficiência (R$ 15 million);
ü Other effects (R$ 4 million);
(ii) Material – increase of 38.5% (R$ 15 million), mainly explained by:
ü RGE Sul acquisition (R$ 9 million);
ü Services business segment increase (R$ 3 million);
ü Distribution segment business increase (R$ 3 million);
(iii) Out-sourced services - increase of 24.1% (R$ 36 million), mainly due to RGE Sul acquisition (R$ 31 million) and other effects (R$ 5 million);
(iv) Other operational costs/expenses - increase of 7.7% (R$ 13 million), mainly due to increase in the expenses in:
ü RGE Sul acquisition (R$ 23 million);
ü Collection fee expenses increase (R$ 4 million);
ü Write-off assets (R$ 3 million);
ü GSF risk premium payment – Conventional Generation segment business and CPFL Renováveis (R$ 2 million);
ü Increase of the expenses with collecting actions (R$ 2 million);
Partially offset by:
ü Reduction in allowance for doubtful account (R$ 7 million);
ü Reduction of 10.3% in legal and judicial expenses (R$ 6 million);
ü Reduction of 18.3% in leases and rental (R$ 2 million);
ü Reduction of regulatory penalties – DIC, FIC, DMIC and DICRI (R$ 1 million);
ü Other effects (R$ 5 million).
Other operating costs and expenses
Other operating costs and expenses reached R$ 820 million in 1Q17, compared to R$ 539 million in 1Q16, registering an increase of 52.1% (R$ 281 million), with the variations below:
· Acquisition of RGE Sul (R$ 133 million);
· Increase of 91.0% (R$ 113 million) in cost of building the concession´s infrastructure;
· Increase of 87.0% (R$ 12 million) in Private Pension Fund expenses, due to actuarial report update;
· Increase of 9.1% (R$ 22 million) in Depreciation and Amortization;
· Increase of 1.3% (R$ 1 million) in Amortization of Intangible of Concession Asset.
Página 17 de 64
In 1Q17, EBITDA reached R$ 1,196 million, registering an increase of 15.6% (R$ 161 million).
EBITDA is calculated according to CVM Instruction no. 527/12 and showed in the table below:
EBITDA and Net Income conciliation (R$ million) | |||
|
1Q17 |
1Q16 |
Var. |
Net Income |
232 |
232 |
-0.1% |
De preciation and Amortization |
377 |
308 |
|
Financial Result |
436 |
319 |
|
Income Tax / Social Contribution |
151 |
175 |
|
EBITDA |
1,196 |
1,035 |
15.6% |
Financial Result (R$ Million) | |||
|
1Q17 |
1Q16 |
Var. |
Revenues |
|||
Income from Financial Investments |
160 |
132 |
20.9% |
Additions and Late Payment Fines |
73 |
57 |
28.1% |
Fiscal Credits Update |
3 |
3 |
0.7% |
Judicial Deposits Update |
13 |
9 |
52.8% |
Monetary and Foreign Exchange Updates |
30 |
55 |
-44.4% |
Discount on Purchase of ICMS Credit |
3 |
7 |
-55.9% |
Sectoral Financial Assets Update |
- |
49 |
- |
PIS and COFINS - over Other Financial Revenues |
(15) |
(21) |
-30.7% |
Others |
13 |
22 |
-42.7% |
Total |
281 |
312 |
-10.1% |
|
|
||
Expenses |
|
|
|
Debt Charges |
(485) |
(431) |
12.7% |
Monetary and Foreign Exchange Updates |
(184) |
(153) |
20.2% |
(-) Capitalized Interest |
24 |
13 |
88.8% |
Sectoral Financial Liabilities Update |
(27) |
(2) |
1431.0% |
Use of Public Asset |
(3) |
(4) |
-13.0% |
Others |
(42) |
(55) |
-24.4% |
Total |
(717) |
(631) |
13.5% |
|
|
||
Financial Result |
(436) |
(319) |
36.7% |
Página 18 de 64
Financial Result (without RGE Sul) (R$ Million) | |||
|
1Q17 |
1Q16 |
Var. |
Revenues |
|||
Income from Financial Investments |
155 |
132 |
17.0% |
Additions and Late Payment Fines |
56 |
57 |
-1.7% |
Fiscal Credits Update |
3 |
3 |
0.7% |
Judicial Deposits Update |
12 |
9 |
43.4% |
Monetary and Foreign Exchange Updates |
31 |
55 |
-43.3% |
Discount on Purchase of ICMS Credit |
3 |
7 |
-55.9% |
Sectoral Financial Assets Update |
- |
49 |
- |
PIS and COFINS - over Other Financial Revenues |
(13) |
(21) |
-38.1% |
Others |
12 |
22 |
-46.7% |
Total |
259 |
312 |
-17.1% |
|
|
||
Expenses |
|
|
|
Debt Charges |
(443) |
(431) |
2.9% |
Monetary and Foreign Exchange Updates |
(180) |
(153) |
18.1% |
(-) Capitalized Interest |
23 |
13 |
82.5% |
Sectoral Financial Liabilities Update |
(26) |
(2) |
1368.3% |
Use of Public Asset |
(3) |
(4) |
-13.0% |
Others |
(37) |
(55) |
-31.8% |
Total |
(667) |
(631) |
5.7% |
|
|
||
Financial Result |
(408) |
(319) |
28.0% |
In the analysis presented in this report, we consider the impact of the inclusion of RGE Sul as an isolated item.
In 1Q17, net financial expense was of R$ 436 million, an increase of 36.7% (R$ 117 million) compared to the net financial expense of R$ 319 million reported in 1Q16.
The items explaining these variations in Financial Result are as follows:
· Financial Revenues: a reduction of 10.1% (R$ 32 million), from R$ 312 million in 1Q16 to R$ 281 million in 1Q17, mainly due to the following factors:
(i) Variation of R$ 49 million in sectoral financial assets update, since there was no balance to be updated in 1Q17 and there was a revenue in the amount of R$ 49 million in 1Q16;
(ii) Reduction of 43.3% (R$ 24 million) in the monetary and foreign exchange updates, due to: (a) the reduction of R$ 13 million in the gain with the zero-cost collar derivative1; (b) the reduction of R$ 8 million in revenues from fines, interest and monetary adjustment relating to installment payments made by consumers; and (c) the reduction of R$ 3 million in the update of the balance of tariff subsidies, as determined by ANEEL;
(iii) Reduction of 46.7% (R$ 10 million) in other financial revenues;
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$. In addition, according to Management’s view, the scenario was favorable for contracting this type of financial instrument, considering the high volatility implicit in dollar options and the fact that there was no initial cost for same.
Página 19 de 64
(iv) Reduction of 55.9% (R$ 4 million) in discount on the acquisition of ICMS credit;
(v) Reduction of 1.7% (R$ 1 million) in additions and late payment fines;
Partially offset by:
(vi) Increase of 17.0% (R$ 23 million) in the income from financial investments, due mainly to the increase in the average balance of investments;
(vii) Impact of the inclusion of RGE Sul in our consolidation in 1Q17. The total financial revenue in relation to RGE Sul (which was not included in our consolidation in 1Q16) totaled R$ 22 million for 1Q17;
(viii) Reduction of 38.1% (R$ 8 million) in PIS and COFINS over Other Financial Revenue (revenue reducer);
(ix) Increase of 43.4% (R$ 4 million) in judicial deposits update.
· Financial Expenses: an increase of 13.5% (R$ 85 million), from R$ 631 million in 1Q16 to R$ 717 million in 1Q17, mainly due to the following factors:
(i) Impact of the inclusion of RGE Sul in our consolidation in 1Q17. The total financial expense in relation to RGE Sul (which was not included in our consolidation in 1Q16) totaled R$ 50 million for 1Q17;
(ii) Increase of 18.1% (R$ 28 million) in the monetary and foreign exchange updates, due to: (a) the mark-to-market negative effect for financial operations under Law 4,131 – non-cash effect (R$ 19 million); (b) the increase of debt charges in foreign currency, with swap to CDI interbank rate (R$ 14 million), reflecting the increase in the stock of debt; partially offset by (c) the effect of Itaipu’s exchange variation (R$ 5 million);
(iii) Increase of R$ 24 million in sectoral financial liabilities update, from an expense of R$ 2 million in 1Q16 to an expense of R$ 26 million in 1Q17;
(iv) Increase of 2.9% (R$ 12 million) of debt charges in local currency, reflecting the increase in the stock of debt;
Partially offset by:
(v) Reduction of 31.8% (R$ 17 million) in other financial expenses;
(vi) Increase of 82.5% (R$ 11 million) in capitalized interest (expense reducer);
(vii) Reduction of 13.0% (R$ 1 million) in the financial expenses with the Use of Public Asset (UBP).
In 1Q17, net income was R$ 232 million, registering a reduction of 0.1%.
Página 20 de 64
1) Do not consider mark-to-market effects and borrowing costs.
Indexation after Hedge1 – 1Q16 vs. 1Q17
1Q16
1Q17
1) For debt linked to foreign currency (24% of total in 1Q17), swaps are contracted, which convert indexing for CDI;
Página 21 de 64
Net Debt and Leverage in IFRS
IFRS - R$ Million |
1Q17 |
1Q16 |
Var. % |
Financial Debt (including hedge) |
(20,866) |
(18,442) |
13.1% |
(+) Available Funds |
4,878 |
4,406 |
10.7% |
(=) Net Debt |
(15,988) |
(14,036) |
13.9% |
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, at the beginning of 2016, CPFL Energia had worked in 2017 and 2018 prefunding.
Debt Amortization Schedule in Financial Covenants Criteria (Mar-17)1
1) Considers only the principal debt of R$ 18,162 million, excluding accrued interests of R$ 546 million and including other adjustments in the amount of R$ 103 million) to reach in the debt value of R$ 18,606 million in the Covenant criteria;
2) Short-term (Apr-17 – Mar-18) = R$ 3,441 million.
The cash position at the end of 1Q17 had a coverage ratio of 1.39x the amortizations of the next 12 months, enough to honor all amortization commitments until the end of 1H18. The average amortization term, calculated by this schedule, is 2.80 years.
Página 22 de 64
Indexation1 After Hedge2 in Financial Covenants Criteria – 1Q16 vs. 1Q17
1Q16
1Q17
1) Considering proportional consolidation of CPFL Renováveis, CERAN, BAESA, ENERCAN, Foz do Chapecó and EPASA;
2) For debt linked to foreign currency (24% of total), swaps are contracted, which convert the indexation to CDI. The debt amount indexed in Interbank Rate (CDI) increased from 74% to 76.0%, mainly due to the R$ 620 million borrowed by CPFL Energia (holding) and R$ 400 million by CPFL Brasil through debentures emission in 4Q16. Additionally, In 1Q17 there were debentures emission in amount of R$ 786 million from RGE, CPFL Piratinga and CPFL Renováveis (holding).
Gross Debt Cost1 in Financial Covenants Criteria – LTM
1) Adjusted by the proportional consolidation since 2012; Financial debt (+) private pension fund (-) hedge.
Página 23 de 64
In 1Q17, Pro forma Net Debt totaled R$ 13,837 million, an increase of 13.0% compared to net debt position at the end of 1Q16 in the amount of R$ 12,241 million.
The increase in Net Debt in 1Q17 was mainly due to the acquisition of RGE Sul, which was consolidated in November 2016.
Covenant Criteria (*) - R$ Million |
1Q17 |
1Q16 |
Var. |
Financial Debt (including hedge)1 |
(18,606) |
(16,478) |
12.9% |
(+) Available Funds |
4,768 |
4,237 |
12.5% |
(=) Net Debt |
(13,837) |
(12,241) |
13.0% |
EBITDA Proforma2 |
4,192 |
3,577 |
17.2% |
Net Debt / EBITDA |
3.30x |
3.42x |
-0.20x |
1) Considering proportional consolidation of CPFL Renováveis, CERAN, BAESA, ENERCAN, Foz do Chapecó and EPASA;
2) Adjusted EBITDA in the 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 adjusted EBITDA the effects of historic EBITDA of newly acquired projects. Considering that, adjusted net debt totaled R$ 13,837 million and EBITDA Proforma in the last 12 months reached R$ 4,192 million, the ratio adjusted Net Debt / EBITDA Proforma at the end of 1Q17 reached 3.30x.
Investments (R$ Million) | |||
Segment |
1Q17 |
1Q16 |
Var. |
Distribution |
347 |
208 |
67.0% |
Generation - Conventional |
0 |
3 |
-89.7% |
Generation - Renewable |
283 |
227 |
24.4% |
Commercialization |
0 |
1 |
-86.7% |
Services and Others1 |
13 |
7 |
80.6% |
Subtotal |
643 |
446 |
44.2% |
Transmission |
38 |
3 |
1102.0% |
Total |
681 |
449 |
51.6% |
Special Obligations |
64 |
44 |
46.8% |
Note:
1) Others – basically refer to assets and transactions that are not related to the listed segments.
In 1Q17, R$ 643 million were invested, an increase of 44.2% if compared to 1Q16. In addition, there was an investment of R$ 38 million in the quarter related to the transmission lines construction of CPFL Transmissão Morro Agudo, which, according to the requirements of IFRIC 12, was recorded as “Financial Asset of Concession” (non-current assets). CPFL Energia also accounted for R$ 64 million in Special Obligations in the quarter, among other items financed by the consumer.
Página 24 de 64
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. Mainly on Campo dos Ventos and São Benedito Wind Complexes;
b. Pedra Cheirosa Wind Complex.
On April 28, 2017, CPFL Energia’s Board of Directors approved Board of Executive Officers’ proposal for 2017 Annual Budget and 2018/2021 Multiannual Plan for the Company, which was previously discussed by the Budget and Corporate Finance Commission. Projections already include expected investments for RGE Sul.
Projected Capital Expenditures (R$ million)1
Notes:
1) Constant currency;
2) Disregard investments in Special Obligations on Distribution segment (among other items financed by consumers);
3) Conventional + Renewable.
Página 25 de 64
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 |
03/31/2016 |
R$ 18.76 |
27,859 |
50,055 |
03/31/2016 |
$ 10.69 |
14,334 |
17,685 |
12/31/2016 |
R$ 24.99 |
36,108 |
60,227 |
12/31/2016 |
$ 15.27 |
18,751 |
19,763 |
03/31/2017 |
R$ 25.77 |
39,971 |
64,984 |
03/31/2017 |
$ 16.39 |
21,073 |
20,663 |
QoQ |
3.1% |
10.7% |
7.9% |
QoQ |
7.3% |
12.4% |
4.6% |
YoY |
37.4% |
43.5% |
29.8% |
YoY |
53.3% |
47.0% |
16.8% |
On March 31, 2017 the price shares closed at R$ 25.77 per share on the B3 and US$ 16.39 per ADR on the NYSE, which represented a variation in the quarter of 3.1% and 7.3% respectively. In the last 12 months, the shares appreciated 37.4% on B3 and the ADR appreciated 53.3% on the NYSE.
The daily trading volume in 1Q17 averaged R$ 49.3 million, of which R$ 34.9 million on the B3 and R$ 14.4 million on the NYSE, representing an increase of 21.1% compared to 1Q16. The number of trades on the B3 decreased by 60.4%, from a daily average of 8,492, in 1Q16, to 3,363, in 1Q17.
Note: Considers the sum of the average daily volume on the B3 and NYSE.
Página 26 de 64
The corporate governance model adopted by CPFL Energia and its subsidiaries is based on the principles of transparency, equity, accountability and corporate responsibility.
In 2016, CPFL marked 12 years since being listed on the BM&FBovespa 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 BM&FBovespa 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, whose term of office is 1 year and who are eligible for reelection. At the Ordinary and Extraordinary General Meetings held on April 28, 2017, 7 members were elected (of which 2 independent members).
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), all coordinated by a director, 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. At a meeting of the Board of Directors, held on February 17, 2017, the new members of the advisory committees were elected.
The Board of Executive Officers is made up of 1 Chief Executive Officer and 6 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. At the Ordinary and Extraordinary General Meetings held on April 28, 2017, among the amendments to the Bylaws, which were approved, is the amendment to article 18, which changes the number of members of the Board of Executive Officers, creates the position of Deputy Chief Executive Officer and modifies the nomenclature of some of the positions of the Board of Executive Officers.
CPFL has a permanent Fiscal Council 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. At the Ordinary and Extraordinary General Meetings held on April 28, 2017, 3 acting members and 3 deputy members were elected.
The guidelines and documents on corporate governance are available at the Investor Relations website http://www.cpfl.com.br/ir.
Página 27 de 64
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 Ltda. (SGBP) and ESC Energia S.A.:
Reference date: 03/31/2017
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) CPFL Energia holds a stake in RGE Sul through the CPFL Jaguariúna.
On May 3, 2017, CPFL Energia released through an Announcement to the Market that, on that date, it was setting up a new company, Envo, to provide distributed solar power generation services to residential as well as small commercial and industrial clients. Envo broadens the portfolio of energy products and services offered by the CPFL Group to its consumers and consolidates the strategy of growth with the focus on sustainable businesses and renewable energy. Envo will initially focus its sales efforts and operations on cities in the region of Campinas, Sorocaba, Jundiaí and surrounding areas. As such, the service will be available to cities in the interior region of São Paulo, such as Jundiaí, Sorocaba, Vinhedo, Hortolândia, Indaiatuba, Valinhos, Paulínia, Americana, Itatiba, Jaguariúna, Piracicaba, Sumaré and Pedreira, in addition to Campinas and other regions. The Company has plans to expand to other regions in the state. CPFL Energia believes that distributed solar power generation is one of the most promising markets in Brazil’s electricity sector and its investment in this segment is in line with the CPFL Group’s efforts to generate new businesses focused on the low carbon economy, such as investments in renewable energy, energy efficiency and digitization of the electricity network, in addition to research in the field of electric mobility and storage. According to the business model, the Company will be responsible for all stages of the project for the client. Envo’s operations will span from technical design (evaluating items such as energy consumption, structural conditions of the building, levels of solar radiation and shadows at the place), as well as the sale and installation of the complete solution, to approval of the consumer at the distributor and intermediating the installation of digital meters. More information is available at the Envo website (www.envo.com.br).
Página 28 de 64
Consolidated Income Statement - Distribution (Pro-forma - R$ Million) | |||
|
1Q17 |
1Q16 |
Var. |
Gross Operating Revenue |
7,536 |
6,686 |
12.7% |
Net Operating Revenue |
4,462 |
3,527 |
26.5% |
Cost of Electric Power |
(2,810) |
(2,225) |
26.3% |
Operating Costs & Expenses |
(1,215) |
(850) |
43.0% |
EBIT |
437 |
452 |
-3.2% |
EBITDA (1) |
626 |
591 |
5.9% |
Financial Income (Expense) |
(182) |
(91) |
99.6% |
Income Before Taxes |
256 |
361 |
-29.2% |
Net Income |
150 |
222 |
-32.3% |
Notes:
(1) EBITDA (IFRS) is calculated from the sum of net income, taxes, financial result and depreciation/amortization, as CVM Instruction no. 527/12;
(2) The distributors’ financial performance tables are attached to this report in item 11.12.
The distribution subsidiaries, aiming at the better presentation of their operational and financial performance, concluded that the adjustment of expectation of the cash flow of the indemnable financial asset of the concession of each distributor, originally presented under financial revenue item, in financial result, should be more adequately classified in the operating revenues group, together with other revenues related to its activity. This allocation reflects more accurately the business model of electric energy distribution and provides a better presentation regarding its performance.
Pursuant to CPC 23 / IAS 8 - Accounting Policies, Changes in Estimates and Error Rectification, by the end of 2016, the CPFL Energia and its Subsidiaries changed their accounting policy previously adopted by an accounting policy that better reflects the performance of the Company's and its subsidiaries' businesses and, therefore, accounting the adjustments to the concession financial asset in Operating Revenues.
In 1Q17, total sectoral financial liabilities accounted for R$ 565 million, a decrease of 22.8% (R$ 167 million) if compared to 1Q16, when sectoral financial liabilities amounted to R$ 732 million.
On March 31, 2017, the balance of sectoral financial assets and liabilities was negative in R$ 1,525 million, compared to a negative balance of R$ 915 million on December 31, 2016 and a positive balance of R$ 707 on March 31, 2016.
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 30 de 64
In the analysis presented in this report, we consider the impact of the inclusion of RGE Sul as an isolated item.
In 1Q17, gross operating revenue amounted to R$ 7,536 million, an increase of 12.7% (R$ 850 million), due to the following factors:
· Acquisition of RGE Sul (R$ 1,344 million);
· Decrease of 38.8% (R$ 284 million) in the Sectoral Financial Liabilities;
· Increase of 24.4% (R$ 62 million) in tariff subsidies (CDE resources), mainly discounts in TUSD (for special consumers) and low-income subsidies, in addition to discounts granted to consumers that obtained an injunction to disoblige the payment of specific components of CDE;
· Increase of 37.8% (R$ 53 million) in Short-term Electric Energy;
· Increase of 3.3% (R$ 2 million) in Other Revenues and Income;
· Increase of 37.0% (R$ 79 million) in revenue from building the infrastructure of the concession;
Partially offset by:
· Decrease of 13.9% (R$ 927 million) in the revenue with energy sales (captive + free clients), due to: (i) the adoption of green tariff flag in January and February 2017, compared to red tariff flag applied in the same period of 2016 (yellow tariff flag was adopted in March 2016 and 2017); (ii) the negative average tariff adjustment in the distribution companies for the period between 1Q16 and 1Q17 (highlight for the average reduction of 7.51% in RGE in June 2016 and of 24.21% in CPFL Piratininga in October 2016); (iii) the stability in the sales volume within the concession area (variation of +0.1%); and
· Decrease of 53.3% (R$ 47 million) in the adjustments to the Concession´s Financial Asset, due to: (i) lower inflation (IPCA of 1.01% in 1Q17 and of 2.64% in 1Q16); and (ii) the reduction in concession’s financial asset observed in the distributors which have gone through the concession renewal process at the end of 2015 (CPFL Santa Cruz, CPFL Leste Paulista, CPFL Sul Paulista, CPFL Jaguari, and CPFL Mococa)2.
Deductions from the gross operating revenue were R$ 3,073 million in 1Q17, representing a reduction of 2.7% (R$ 85 million), due to the following decreases:
· of 91.1% in tariff flags approved by the CCEE (R$ 320 million);
· of 13.7% in ICMS tax (R$ 180 million);
· of 15.4% in the CDE sector charge (R$ 130 million), due to the adoption of CDE System Usage quotas in lower amount than 2016, partially offset by the increase in CDE Energy quotas and in the CDE charges in order to cover ACR Account loans;
· of 8.9% in PIS and COFINS taxes (R$ 53 million);
Partially offset by the following factors:
· acquisition of RGE Sul (R$ 577 million);
· increase of 92.4% in the PROINFA (R$ 19 million); and
2 In order to calculate the split between the intangible asset and concession’s financial asset, it must be considered the useful life of assets. The portion of the useful life that will occur by the end of the concession is classified as an intangible asset and the residual value is classified as concession’s financial asset, referring to the compensation that the distributor will receive when the assets are reversed to the Grantor.
Página 31 de 64
· increase of 4.2% in the R&D and Energy Efficiency Program (R$ 1 million).
Net operating revenue reached R$ 4,462 million in 1Q17, representing an increase of 26.5% (R$ 935 million).
In the analysis presented in this report, we consider the impact of the inclusion of RGE Sul as an isolated item.
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$ 2,810 million in 1Q17, representing an increase of 26.3% (R$ 585 million):
· The cost of electric power purchased for resale was R$ 2,633 million in 1Q17, representing an increase of 39.9% (R$ 751 million), due to the following factors:
(i) Acquisition of RGE Sul (R$ 419 million);
(ii) Increase of 26.0% (R$ 396 million) in the cost of energy purchased in the regulated environment and bilateral contracts, mainly due to the increase of 5.4% (537 GWh) in the volume of purchased energy and the 19.5% increase in the average purchase price (from R$ 153.97/MWh in 1Q16 to R$ 184.02/MWh in 1Q17);
(iii) Increase of R$ 53 million in the cost of energy purchased in the short term and Proinfa, mainly due to the higher average PLD (from R$ 34.60/MWh in 1Q16 to R$ 155.37/MWh in 1Q17, in the Southeast/Midwest and South submarkets), despite the decrease in the average purchase price of Proinfa (from R$ 411.16/MWh in 1Q16 to R$ 264.07/MWh in 1Q17) and the decrease of 2.2% (5 GWh) in the volume of purchased energy;
Partially offset by:
(iv) Decrease of 15.2% (R$ 83 million) in the cost of energy from Itaipu, due to the 11.9% decrease in the average purchase price (from R$ 217.28/MWh in 1Q16 to R$ 191.38/MWh in 1Q17) and by the reduction of 3.8% (94 GWh) in the volume of purchased energy; and
(v) Decrease of 17.6% (R$ 34 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$ 177 million in 1Q17, representing a decrease of 48.3% (R$ 166 million), due to the following factors:
(i) Variation of R$ 198 million in the system service usage charges – ESS, from an expense of R$ 127 million in 1Q16 to a revenue of R$ 71 million in 1Q17;
(ii) Variation of R$ 31 million in the energy reserve charges – EER, since there was no registration in 1Q17 and there was a registration in the amount of R$ 31 million in 1Q16;
Partially offset by:
(iii) Acquisition of RGE Sul (R$ 38 million);
(iv) Decrease of 59.3% (R$ 21 million) in PIS and COFINS tax credits (cost reducer), generated from the charges; and
(v) Increase of 1.9% (R$ 4 million) in the basic network, connection, use of the distribution system and Itaipu transmission charges.
Página 32 de 64
In the analysis presented in this report, we consider the impact of the inclusion of RGE Sul as an isolated item.
Operating costs and expenses reached R$ 1,215 million in 1Q17, compared to R$ 850 million in 1Q16, an increase of 43.0% (R$ 365 million), due to the following factors:
PMSO
PMSO reached R$ 619 million in 1Q17, an increase of 28.4% (R$ 137 million), compared to R$ 482 million in 1Q16. Disregarding the acquisition of RGE Sul, PMSO would increase 6.7% (R$ 32 million).
Página 33 de 64
Reported PMSO (R$ million) | ||||
|
1Q17 |
1Q16 |
Variation | |
|
R$ MM |
% | ||
Reported PMSO |
|
|
|
|
Personnel |
(223.8) |
(165.7) |
(58.1) |
35.0% |
Material |
(38.8) |
(28.3) |
(10.5) |
37.1% |
Outsourced Services |
(194.4) |
(144.1) |
(50.3) |
34.9% |
Other Operating Costs/Expenses |
(162.3) |
(144.3) |
(18.0) |
12.5% |
Allowance for doubtful accounts |
(47.0) |
(45.4) |
(1.6) |
3.5% |
Legal, judicial and indemnities expenses |
(45.8) |
(50.5) |
4.7 |
-9.3% |
Others |
(69.5) |
(48.4) |
(21.1) |
43.5% |
Total Reported PMSO |
(619.4) |
(482.5) |
(136.8) |
28.4% |
|
|
|
|
|
PMSO RGE Sul |
|
|
|
|
Personnel |
(41.5) |
|
|
|
Material |
(8.7) |
|
|
|
Outsourced Services |
(31.1) |
|
|
|
Other Operating Costs/Expenses |
(23.2) |
|
|
|
Allowance for doubtful accounts |
(8.0) |
|
|
|
Legal, judicial and indemnities expenses |
(1.7) |
|
|
|
Others |
(13.5) |
|
|
|
Total PMSO RGE Sul |
(104.6) |
|
|
|
|
|
|
|
|
PMSO (-) RGE Sul |
|
|
|
|
Personnel |
(182.3) |
(165.7) |
(16.5) |
10.0% |
Material |
(30.1) |
(28.3) |
(1.8) |
6.3% |
Outsourced Services |
(163.3) |
(144.1) |
(19.2) |
13.3% |
Other Operating Costs/Expenses |
(139.1) |
(144.3) |
5.2 |
-3.6% |
Allowance for doubtful accounts |
(39.0) |
(45.4) |
6.4 |
-14.2% |
Legal, judicial and indemnities expenses |
(44.1) |
(50.5) |
6.4 |
-12.7% |
Others |
(56.0) |
(48.4) |
(7.6) |
15.7% |
Total PMSO (-) RGE Sul |
(514.8) |
(482.5) |
(32.3) |
6.7% |
Página 34 de 64
Personnel – increase of 35.0% (R$ 58 million), mainly due to the acquisition of RGE Sul (R$ 42 million), of the collective bargaining agreement effects (R$ 14 million) and others (R$ 2 million);
Material – increase of 37.1% (R$ 10 million), mainly due to the acquisition of RGE Sul (R$ 9 million) and the replacement of material to the maintenance of lines and grid (R$ 1 million);
Outsourced services – increase of 34.9% (R$ 50 million), mainly due to the following items: acquisition of RGE Sul (R$ 31 million), outsourced services (R$ 10 million), meter reading and use (R$ 2 million), tree pruning (R$ 1 million), and collection actions (R$ 1 million);
Other operating costs/expenses – increase of 12.5% (R$ 18 million), mainly due to the following factors: acquisition of RGE Sul (R$ 23 million), assets write-off (R$ 2 million) and other expenses (R$ 4 million). These effects were partially offset by the decrease in the allowance for doubtful accounts (R$ 6 million) and in legal and judicial expenses (R$ 6 million).
Other operating costs and expenses
Other operating costs and expenses reached R$ 595 million in 1Q17, compared to R$ 367 million in 1Q16, registering an increase of 62.2% (R$ 228 million), with the variations below:
(i) Acquisition of RGE Sul (R$ 133 million);
(ii) Increase of 37.0% (R$ 79 million) in cost of building the concession´s infrastructure. This item, which reached R$ 294 million in 1Q17, does not affect results, since it has its counterpart in “operating revenue”;
(iii) Increase of 87.6% (R$ 12 million) in Private Pension Fund expenses, due to actuarial report update; and
(iv) Increase of 3.6% (R$ 4 million) in Depreciation and Amortization;
EBITDA totaled R$ 626 million in 1Q17, registering an increase of 5.9% (R$ 35 million).
Conciliation of Net Income and EBITDA (R$ million) | |||
|
1Q17 |
1Q16 |
Var. |
Net income |
150 |
222 |
-32.3% |
Depreciation and Amortization |
189 |
139 |
|
Financial Results |
182 |
91 |
|
Income Tax /Social Contribution |
105 |
139 |
|
EBITDA |
626 |
591 |
5.9% |
In the analysis presented in this report, we consider the impact of the inclusion of RGE Sul as an isolated item.
In 1Q17, the net financial result recorded a net financial expense of R$ 182 million, an increase of 99.6% (R$ 91 million).
Página 35 de 64
The items explaining these changes are as follows:
· Financial Revenue: decrease of 18.9% (R$ 41 million), from R$ 219 million in 1Q16 to R$ 177 million in 1Q17, mainly due to the following factors:
(i) Variation of R$ 49 million in sectoral financial assets update, since there was no balance to be updated in 1Q17 and there was a revenue in the amount of R$ 49 million in 1Q16;
(ii) Decrease of 45.4% (R$ 12 million) in adjustments for inflation and exchange rate changes, due to the decrease of R$ 8 million in revenues from fines, interest and monetary adjustment relating to installment payments made by consumers and the decrease of R$ 3 million in the adjustment of the balance of tariff subsidies, as determined by Aneel;
(iii) Decrease of 7.7% (R$ 6 million) in the income from financial investments, due to the lower average balance of investments;
(iv) Decrease of 55.9% in the discount on purchase of ICMS credit (R$ 4 million);
(v) Decrease of 2.1% in late payment interest and fines (R$ 1 million);
Partially offset by:
(vi) Acquisition of RGE Sul (R$ 22 million);
(vii) Decrease of 50.2% in PIS and Cofins on financial revenues (R$ 9 million); and
(viii) Increase of 45.3% in adjustments for inflation of escrow deposits (R$ 4 million).
· Financial Expense: increase of 16.0% (R$ 49 million), from R$ 310 million in 1Q16 to R$ 359 million in 1Q17, mainly due to the following factors:
(i) Acquisition of RGE Sul (R$ 50 million);
(ii) Increase of R$ 24 million in the adjustments of the sectoral financial liability; and
(iii) Increase of 13.9% (R$ 15 million) in adjustments for inflation and exchange rate changes, due to: (a) the mark-to-market positive effect for financial operations under Law 4,131 – non-cash effect (R$ 12 million); (b) the increase of debt charges in foreign currency, with swap to CDI interbank rate (R$ 8 million); partially offset by (c) the effect of exchange variation in Itaipu invoices (R$ 5 million);
Partially offset by:
(iv) Decrease of 17.7% (R$ 29 million) in interest on debt in local currency;
(v) Decrease of 26.0% (R$ 9 million) in other financial expenses; and
(vi) Increase of 69.6% (R$ 2 million) in capitalized interest.
In 1Q17, a Net Income of R$ 150 million was registered, a decrease of 32.3% (R$ 72 million) if compared to the Net Income of R$ 222 million observed in 1Q16.
Página 37 de 64
Reference dates
Tariff Process Dates | |
Disco |
Date |
CPFL Santa Cruz |
March 22nd* |
CPFL Leste Paulista |
March 22nd* |
CPFL Jaguari |
March 22nd* |
CPFL Sul Paulista |
March 22nd* |
CPFL Mococa |
March 22nd* |
CPFL Paulista |
April 8th |
RGE Sul |
April 19th |
RGE |
June 19th |
CPFL Piratininga |
October 23rd |
Tariff Revision | |||
Distributor |
Periodicity |
Next Revision |
Cycle |
CPFL Paulista |
Every 5 years |
April 2018 |
4th PTRC |
RGE Sul |
Every 5 years |
April 2018 |
4th PTRC |
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 |
CPF Leste Paulista |
Every 5 years |
March 2021* |
5th PTRC |
CPFL Jaguari |
Every 5 years |
March 2021* |
5th PTRC |
CPFL Sul Paulista |
Every 5 years |
March 2021* |
5th PTRC |
CPFL Mococa |
Every 5 years |
March 2021* |
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 the last 12 months
|
CPFL Paulista |
RGE Sul |
RGE |
CPFL Piratininga |
CPFL Santa Cruz |
CPFL Leste Paulista |
CPFL Jaguari |
CPFL Sul Paulista |
CPFL Mococa |
Ratifying Resolution |
2,056 |
2,059 |
2,082 |
2,157 |
2,211 |
2,210 |
2,213 |
2,209 |
2,212 |
Adjustment |
9.89% |
3.94% |
-1.48% |
-12.54% |
-1.28% |
0.77% |
2.05% |
1.63% |
1.65% |
Parcel A |
-2.06% |
-3.75% |
-2.98% |
-7.02% |
0.88% |
1.26% |
3.26% |
0.44% |
2.78% |
Parcel B |
1.78% |
1.86% |
2.31% |
1.67% |
0.48% |
1.92% |
0.62% |
0.53% |
0.67% |
Financial Components |
10.18% |
5.83% |
-0.81% |
-7.19% |
-2.65% |
-2.41% |
-1.83% |
0.66% |
-1.80% |
Effect on consumer billings |
7.55% |
-0.34% |
-7.51% |
-24.21% |
-10.37% |
-3.28% |
-8.41% |
-4.15% |
-2.56% |
Date of entry into force |
4/8/2016 |
4/19/2016 |
6/19/2016 |
10/23/2016 |
3/22/2017 |
3/22/2017 |
3/22/2017 |
3/22/2017 |
3/22/2017 |
Página 38 de 64
Annual tariff adjustments occurred in April-2017
|
CPFL Paulista |
RGE Sul |
Ratifying Resolution |
2,217 |
2,218 |
Adjustment |
-0.80% |
-0.20% |
Parcel A |
1.37% |
2.32% |
Parcel B |
0.76% |
0.63% |
Financial Components |
-2.93% |
-3.15% |
Effect on consumer billings |
-10.50% |
-6.43% |
Date of entry into force |
4/8/2017 |
4/19/2017 |
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.
SAIDI and SAIFI Indexes1 | ||||||||||||
Distributor |
SAIDI (hours) |
SAIFI (interruptions) | ||||||||||
2013 |
2014 |
2015 |
2016 |
1Q17 |
ANEEL1 |
2013 |
2014 |
2015 |
2016 |
1Q17 |
ANEEL1 | |
CPFL Paulista |
7.14 |
6.93 |
7.76 |
7.62 |
7.33 |
7.50 |
4.73 |
4.88 |
4.89 |
5.00 |
4.89 |
6.53 |
CPFL Piratininga |
7.44 |
6.98 |
7.24 |
6.97 |
8.82 |
6.86 |
4.58 |
4.19 |
4.31 |
3.80 |
4.28 |
6.03 |
RGE |
17.35 |
18.77 |
15.98 |
14.44 |
14.43 |
12.15 |
9.04 |
9.14 |
8.33 |
7.56 |
7.82 |
9.10 |
RGE Sul |
14.07 |
17.75 |
19.11 |
19.45 |
17.34 |
11.42 |
7.39 |
8.87 |
8.42 |
9.41 |
8.84 |
9.11 |
CPFL Santa Cruz |
6.97 |
6.74 |
8.46 |
5.65 |
5.38 |
9.26 |
6.82 |
5.29 |
6.34 |
4.09 |
3.79 |
8.85 |
CPFL Jaguari |
5.92 |
5.41 |
6.93 |
7.10 |
7.81 |
8.26 |
5.43 |
4.32 |
4.61 |
6.13 |
7.34 |
7.43 |
CPFL Mococa |
4.86 |
6.88 |
7.04 |
10.56 |
10.30 |
9.95 |
4.93 |
7.31 |
5.92 |
6.63 |
6.33 |
8.99 |
CPFL Leste Paulista |
7.58 |
8.48 |
7.92 |
8.01 |
8.19 |
9.73 |
6.33 |
6.30 |
5.67 |
5.73 |
5.69 |
8.18 |
CPFL Sul Paulista |
9.08 |
9.69 |
11.51 |
15.20 |
12.62 |
9.95 |
6.71 |
7.03 |
9.47 |
11.76 |
9.98 |
8.29 |
1) Regulatory Agency (ANEEL) Limits – 2017.
In 1Q17, CPFL Piratininga’s SAIDI increased significantly in relation to 2016, due to the occasional disconnections of great impact mainly in the transmission system.
On the other hand, CPFL Sul Paulista’s and RGE Sul's SAIDI registered a reduction in 1Q17 in relation to 2016, demonstrating the effectiveness of maintenance and improvement works, and also because, in 1Q17, we have more favorable weather conditions than in 2016, when we were still suffering the effects of what was considered the strongest El Niño of the last 15 years.
The SAIFI indicator was kept below regulatory limits in all companies (except CPFL Sul Paulista), reflecting the effectiveness of the maintenance performed and the constant investments in improvements and modernization carried out by CPFL.
The abnormal atmospheric conditions at the end of 2015 and early 2016 have more severely affected CPFL Sul Paulista, negatively impacting both SAIFI and SAIDI results.
Página 39 de 64
Losses
Find below the performance of CPFL distribution companies throughout the last quarters:
12M Accumulated Losses1 |
Technical Losses |
Non-Technical Losses |
Total Losses | ||||||||||||
2Q16 |
3Q16 |
4Q16 |
1Q17 |
ANEEL2 |
2Q16 |
3Q16 |
4Q16 |
1Q17 |
ANEEL2 |
2Q16 |
3Q16 |
4Q16 |
1Q17 |
ANEEL2 | |
CPFL Energia |
6.44% |
6.39% |
6.35% |
6.33% |
6.39% |
2.71% |
2.63% |
3.00% |
2.95% |
1.83% |
9.14% |
9.02% |
9.34% |
9.28% |
8.22% |
CPFL Paulista |
6.77% |
6.72% |
6.55% |
6.33% |
6.32% |
2.59% |
2.65% |
3.03% |
3.32% |
1.98% |
9.36% |
9.36% |
9.58% |
9.65% |
8.30% |
CPFL Piratininga |
4.29% |
4.34% |
4.45% |
4.72% |
5.52% |
2.73% |
2.71% |
2.85% |
2.79% |
1.45% |
7.02% |
7.05% |
7.30% |
7.52% |
6.97% |
RGE |
7.45% |
7.39% |
7.35% |
7.39% |
7.28% |
2.66% |
2.31% |
2.64% |
2.46% |
1.91% |
10.11% |
9.70% |
9.99% |
9.85% |
9.19% |
RGE Sul |
7.28% |
7.05% |
7.08% |
7.26% |
6.75% |
3.53% |
3.17% |
4.00% |
2.91% |
2.20% |
10.82% |
10.22% |
11.07% |
10.17% |
8.95% |
CPFL Santa Cruz |
8.79% |
8.65% |
8.75% |
8.74% |
7.76% |
0.81% |
1.15% |
1.08% |
1.24% |
0.51% |
9.60% |
9.80% |
9.82% |
9.98% |
8.27% |
CPFL Jaguari |
3.54% |
3.45% |
3.37% |
3.33% |
4.28% |
1.65% |
1.17% |
1.26% |
1.07% |
0.41% |
5.19% |
4.62% |
4.63% |
4.40% |
4.69% |
CPFL Mococa |
7.84% |
7.74% |
7.46% |
7.29% |
8.17% |
2.52% |
2.43% |
2.83% |
3.23% |
0.57% |
10.36% |
10.17% |
10.29% |
10.52% |
8.74% |
CPFL Leste Paulista |
8.51% |
8.57% |
8.49% |
8.37% |
7.99% |
2.94% |
3.24% |
2.39% |
2.20% |
0.82% |
11.44% |
11.81% |
10.88% |
10.57% |
8.81% |
CPFL Sul Paulista |
7.83% |
8.13% |
8.26% |
8.42% |
5.94% |
1.24% |
1.46% |
1.83% |
1.80% |
0.22% |
9.07% |
9.59% |
10.08% |
10.22% |
6.16% |
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, already considering RGE Sul in the historical series, was from 8.89% in 1Q16 to 9.28% in 1Q17, an increase of 0.39 b.p. This increase is mainly due to changes in the market breakdown, with increasing low voltage customers share, increase of energy injected in distribution lines (energy generated in SHPPs and transmitted to basic network) and worse macroeconomic scenario.
Find below how was performance of losses in low voltage market:
12-month Accumulated Losses - LV1 |
Non-technical Losses / LV | ||||
2Q16 |
3Q16 |
4Q16 |
1Q17 |
ANEEL2 | |
CPFL Paulista |
6.04% |
6.19% |
7.13% |
7.82% |
4.61% |
CPFL Piratininga |
7.81% |
7.69% |
8.05% |
7.89% |
3.90% |
RGE |
6.58% |
5.66% |
6.51% |
6.07% |
4.41% |
RGE Sul |
8.12% |
7.23% |
9.24% |
6.64% |
4.91% |
CPFL Santa Cruz |
1.57% |
2.27% |
2.17% |
2.50% |
0.98% |
CPFL Jaguari |
6.76% |
4.77% |
5.04% |
4.32% |
1.60% |
CPFL Mococa |
4.44% |
4.29% |
5.01% |
5.73% |
0.98% |
CPFL Leste Paulista |
5.19% |
5.82% |
4.32% |
3.99% |
1.46% |
CPFL Sul Paulista |
2.91% |
3.25% |
3.95% |
3.90% |
0.46% |
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.
Página 40 de 64
Consolidated Income Statement - Commercialization (R$ Million) | |||
|
1Q17 |
1Q16 |
Var. |
Net Operating Revenue |
621 |
432 |
43.8% |
EBITDA(1) |
41 |
17 |
141.8% |
Net Income |
17 |
14 |
23.5% |
Note:
(1) EBITDA is calculated from the sum of net income, taxes, financial result and depreciation/amortization.
Operating Revenue
In 1Q17, net operating revenue reached R$ 621 million, representing an increase of 43.8% (R$ 189 million).
EBITDA
In 1Q17, EBITDA totaled R$ 41 million, compared to R$ 17 million in 1Q16, an increase of 141.8% (R$ 24 million).
Net Income
In 1Q17, net income amounted to R$ 17 million, compared to R$ 14 million in 1Q16, an increase of 23.5% (R$ 3 million).
Consolidated Income Statement - Services (R$ Million) | |||
|
1Q17 |
1Q16 |
Var. |
Net Operating Revenue |
103 |
85 |
21.0% |
EBITDA(1) |
18 |
18 |
0.8% |
Net Income |
11 |
10 |
2.5% |
Note:
(1) EBITDA is calculated from the sum of net income, taxes, financial result and depreciation/amortization.
Operating Revenue
In 1Q17, net operating revenue reached R$ 103 million, representing an increase of 21.0% (R$ 18 million).
EBITDA
In 1Q17, EBITDA totaled R$ 18 million, compared to R$ 18 million in 1Q16, an increase of 0.8%.
Net Income
In 1Q17, net income amounted to R$ 11 million, compared to R$ 10 million in 1Q16, an increase of 2.5%.
Página 41 de 64
Consolidated Income Statement - Conventional Generation (R$ Million) | |||
|
1Q17 |
1Q16 |
Var. |
Gross Operating Revenue |
282 |
261 |
8.2% |
Net Operating Revenue |
257 |
237 |
8.6% |
Cost of Electric Power |
(22) |
(26) |
-14.4% |
Operating Costs & Expenses |
(56) |
(57) |
-1.1% |
EBITDA(1) |
290 |
249 |
16.4% |
Net Income |
132 |
110 |
20.1% |
Nota:
(1) EBITDA is calculated from the sum of net income, taxes, financial result and depreciation/amortization.
In 1Q17, Gross Operating Revenue reached R$ 282 million, an increase of 8.2% (R$ 21 million) in relation to 1Q16.
The variation in the gross operating revenue is mainly due to the following factors:
Partially offset by:
Net Operating Revenue reached R$ 257 million, registering an increase of 8.6% (R$ 20 million).
In 1Q17, the cost of electric power reached R$ 22 million, a reduction of 14.4% (R$ 4 million), due mainly to the following factors:
· Reduction of 22.3% in the cost with Electric Energy Purchased for Resale (R$ 4 million), due mainly to the following factors:
Página 42 de 64
In CPFL Geração (controlling company), decrease of R$ 8 million:
(i) Reduction in the cost of energy from Barra Grande HPP (Baesa) (R$ 8 million) due to the reduction of 41.7% in the average sales price;
In Rio das Antas Complex (Ceran), Paulista Lajeado HPP and Centrais Geradoras, increase of R$ 4 million:
(i) Increase of R$ 3 million in the energy cost from the plants of CPFL Centrais Geradoras;
(ii) Increase of R$ 1 million in the energy cost from the plants of Rio das Antas Complex (Ceran).
· Increase of 12.4% in the cost with Charges for the Use of the Transmission and Distribution System (R$ 1 million).
In 1Q17, operating costs and expenses reached R$ 56 million, compared to R$ 57 million in 1Q16, a reduction of 1.1% (R$ 1 million), due to the variations in:
(i) PMSO item, that reached R$ 25 million in 1Q17, compared to R$ 25 million in 1Q16, registering a reduction of 2.8% (R$ 1 million). The table below lists the main variation in PMSO:
Consolidated Income Statement - Conventional Generation (R$ million) | |||
|
1Q17 |
1Q16 |
Var. |
Gross Operating Revenue |
282 |
261 |
8.2% |
Net Operating Revenue |
257 |
237 |
8.6% |
Cost of Electric Power |
(22) |
(26) |
-14.4% |
Operating Costs & Expenses |
(56) |
(57) |
-1.1% |
EBIT |
179 |
155 |
16.0% |
EBITDA |
290 |
249 |
16.4% |
Financial Income (Expense) |
(100) |
(84) |
19.5% |
Income Before Taxes |
159 |
134 |
18.3% |
Net Income |
132 |
110 |
20.1% |
This variation is explained mainly by the following factors:
i. Personnel expenses, which registered an increase of 11.8% (R$ 1 million);
ii. Increase in Material, which registered a decrease of 35.0% (R$ 0.2 million);
iii. Increase of 18.4% in Outsourced Services (R$ 1 million);
iv. Reduction of 21.3% in Other Operating Costs/Expenses (R$ 2 million).
(ii) Reduction of 0.5% in Depreciation and Amortization;
Página 43 de 64
Equity Income (R$ Million) | ||||
|
1Q17 |
1Q16 |
Var. R$ |
Var. % |
Projects |
||||
Barra Grande HPP |
1 |
7 |
(6) |
-82.2% |
Campos Novos HPP |
34 |
23 |
11 |
50.6% |
Foz do Chapecó HPP |
25 |
18 |
7 |
37.7% |
Epasa TPP |
19 |
15 |
4 |
24.2% |
Total |
80 |
63 |
16 |
25.6% |
In 1Q17, Equity Income reached R$ 80 million, compared to R$ 63 million in 1Q16, an increase of 25.6% (R$ 16 million).
Barra Grande HPP (-R$ 6 million):
· Reduction of 27.6% in Net Revenue (R$ 5 million);
· Increase in Operating Costs and Expenses (R$ 7 million);
· Reduction of 5.9% (R$ 0.1 million) in Depreciation and Amortization;
· Increase of 99.0% in Net Financial Expense (R$ 0.2 million);
· Reduction of the expense with Income Tax and Social Contribution (R$ 3 million);
· Reduction of 82.2% in Net Income (R$ 6 million).
Foz do Chapecó HPP (R$ 7 million):
· Increase of 6.5% in Net Revenue (R$ 6 million);
· Increase of 20.5% in Operating Costs and Expenses (R$ 4 million);
· Reduction of 0.9% in Depreciation and Amortization (R$ 0.2 million);
· Reduction of 6.2% in Net Financial Expense (R$ 1 million);
· Increase of the expense with Income Tax and Social Contribution (R$ 6 million);
· Increase of 37.7% in Net Income (R$ 7 million).
Campos Novos HPP (R$ 11 million):
· Increase of 4.4% in Net Revenue (R$ 3 million);
· Reduction of 32.1% in Operating Costs and Expenses (R$ 7 million);
· Reduction of 0.6% (R$ 0.1 million) in Depreciation and Amortization;
· Reversion of negative Net Financial Result in 1Q16 of R$ 1 million to positive Net Financial Result of R$ 2 million (variation of R$ 3 million);
· Increase of the expense with Income Tax and Social Contribution (R$ 6 million);
· Increase of 50.6% in Net Income (R$ 11 million).
Página 44 de 64
EPASA TPP (R$ 4 million):
· Increase of 20.7% in Net Revenue (R$ 15 million);
· Increase of 32.9% in operating costs and expenses (R$ 15 million);
· Reduction of 0.4% in Depreciation and Amortization;
· Increase of 19.5% in Net Financial Expense;
· Increase of the expense with Income Tax and Social Contribution (R$ 6 million);
· Increase of 50.6% in Net Income (R$ 11 million).
In 1Q17, EBITDA was of R$ 290 million, compared to R$ 249 million in 1Q16, an increase of 16.4% (R$ 41 million).
Conciliation of Net Income and EBITDA (R$ million) | |||
|
1Q17 |
1Q16 |
Var. |
Net Income |
132 |
110 |
20.1% |
Depreciation and Amortization |
31 |
31 |
|
Financial Result |
100 |
84 |
|
Income Tax /Social Contribution |
27 |
25 |
|
EBITDA |
290 |
249 |
16.4% |
Página 45 de 64
In 1Q17, the financial result was a net expense of R$ 100 million, representing an increase of 19.5% (R$ 16 million).
· Financial Revenues moved from R$ 45 million in 1Q16 to R$ 50 million in 1Q17, an increase of 12.6% (R$ 6 million), due to:
ü Increase of 124.0% in income from financial investments (R$ 19 million);
Partially offset by:
ü Reduction of 40.5% in monetary and foreign exchange updates (R$ 12 million);
ü Increase of 93.9% of PIS and COFINS on other finance income (R$ 1 million).
· Financial Expenses moved from R$ 129 million in 1Q16 to R$ 151 million in 1T17, an increase of 17,1% (R$ 22 million), due to:
ü Increase of 331.8% in monetary and foreign exchange updates (R$ 24 million);
ü Increase of 1.4% in debt charges (R$ 2 million);
Partially offset by:
ü Reduction of 13.0% in expenses of the Use of Public Asset (UBP) (R$ 1 million);
ü Reduction of R$ 3 million in other effects.
In 1Q17, net income was of R$ 132 million, compared to a net income of R$ 110 million in 1Q16, an increase of 20.1%.
Consolidated Income Statement - CPFL Renováveis (100% Participation - R$ Million) | |||
|
1Q17 |
1Q16 |
Var. % |
Gross Operating Revenue |
409 |
308 |
32.9% |
Net Operating Revenue |
387 |
291 |
33.2% |
Cost of Electric Power |
(51) |
(31) |
63.2% |
Operating Costs & Expenses |
(251) |
(225) |
11.3% |
EBIT |
86 |
34 |
148.8% |
EBITDA (1) |
236 |
168 |
41.0% |
Financial Income (Expense) |
(124) |
(134) |
-7.8% |
Income Before Taxes |
(38) |
(100) |
-61.9% |
Net Income |
(50) |
(107) |
-53.1% |
Note:
(1) EBITDA is calculated from the sum of net income, taxes, financial result and depreciation/amortization.
In 1Q17, the variations in the Income Statement of CPFL Renováveis are mainly due to the factors below:
· Commercial start-up of Mata Velha SHPP in May 2016 (24.0 MW);
· Commercial start-up of Campo dos Ventos Complex and São Benedito Complex wind farms, gradually, over 2016 (231.0 MW).
Página 46 de 64
Gross Operating Revenue reached R$ 408 million in 1Q17, representing an increase of 32.9% (R$ 101 million).
Net Operating Revenue reached R$ 387 million in 1Q17, representing an increase of 33.2% (R$ 97 million). This increase is mainly due to the following factors:
Wind (R$ 50 million):
(i) Commercial startup of the Campo dos Ventos and São Benedito wind complexes in May 2016 (R$ 36 million);
(ii) Higher energy volume generated due to higher wind speed in 1Q17 and contractual price adjustment (R$ 14 million);
SHPP (R$ 33 million):
(iii) Commercial startup of SHPP Mata Velha in May 2016 (R$ 5 million);
(iv) Different seasonal adjustment strategy for physical guarantee and contractual price adjustment (R$ 22 million);
(v) Higher revenue from the holding company mainly due to the settlement of energy purchase to rebuild guarantees and the assets’ moving average, which were offset by the cost of energy purchase (R$ 6 million);
Biomass (R$ 10 million):
(vi) As from 1Q17, biomass revenue (excluding plants with an energy sale agreement in the regulated market – Bio Pedra, Bio Ester and Bio Formosa) started being recognized based on the seasonal adjustment of the physical guarantee of agreements, while a portion of biomass generation in 1Q16 was recognized based on generation.
The variation is also impacted by intercompany transactions of CPFL Renováveis with CPFL Brasil and Group’s distributors, which are eliminated in the consolidation of CPFL Energia (R$ 4 million).
In 1Q17, Cost of Electric Power was of R$ 51 million, representing na increase of 63.2% (R$ 20 million). This increase is due to the following factors:
· Increase of 107.8% in the cost with Electric Energy Purchased for Resale (R$ 14 million), mainly due to the the purchase of energy to the meet exposure in the spot market and hedge;
· Increase of 31.0% in cost with Charges for the Use of the Transmission and Distribution System (R$ 6 million):
(i) Start of contractual commitments for use and connection with distribution and transmission companies and the ONS due to the operational startup in the last 12 months;
(ii) Higher energy generation between the periods being compared (+11.2% in 1Q17);
(iii) Impact of the annual adjustment of connection charges and use and connection fees for the distribution and transmission system.
Página 47 de 64
In 1Q17, Operating Costs and Expenses reached R$ 251 million, representing an increase of 11.3% (R$ 26 million). The main factors were:
· PMSO item, which reached R$ 100 million, an increase of 8.7% (R$ 8 million).
The table below shows a summary of the main variations in PMSO:
PMSO (R$ million) | ||||
|
1Q17 |
1Q16 |
Variation |
|
|
R$ MM |
% | ||
Reported PMSO |
|
|
|
|
Personnel |
(22.9) |
(20.3) |
(2.6) |
12.7% |
Material |
(4.9) |
(3.5) |
(1.4) |
38.9% |
Outsourced Services |
(46.3) |
(42.1) |
(4.2) |
9.9% |
Other Operating Costs/Expenses |
(25.7) |
(25.9) |
0.1 |
-0.6% |
GSF Risk Premium |
(0.6) |
- |
(0.6) |
- |
Others |
(25.1) |
(25.9) |
0.7 |
-2.9% |
Total PMSO |
(99.8) |
(91.8) |
(8.0) |
8.7% |
This variation is explained mainly by the following factors:
(i) Personnel: Increase of 12.7% (R$ 3 million), as a result of the higher number of employees and the collective bargaining agreement;
(ii) Material and Outsourced Services: Increase of 12.2% (6 million) mainly due to increase in expenses with consulting services and lawyers fees related to corporate projects;
Partially offset:
(iii) Others: reduction of R$ 1 million.
· Depreciation and Amortization item, which reached R$ 112 million, an increase of 17.5% (R$ 17 million), due basically to the start-up of assets over the last 12 months.
In 1Q17, EBITDA was of R$ 236 million, compared to R$ 168 million in 1Q16, an increase of 41.0% (R$ 69 million).
Conciliation of Net Income and EBITDA (R$ million) | |||
|
1Q17 |
1Q16 |
Var. |
Net income |
(50) |
(107) |
-53.1% |
Amortization |
151 |
133 |
|
Financial Results |
124 |
134 |
|
Income Tax /Social Contribution |
12 |
7 |
|
EBITDA |
236 |
168 |
41.0% |
Página 48 de 64
In 1Q17, net Financial Result was an expense of R$ 124 million, representing a reduction of 7.8% (R$ 10 million) compared to 1Q16.
The main factors that affected the financial revenue (increase of R$ 9 million) were:
(i) Increase of the income from the financial investments (R$ 10 million);
Partially offset by:
(ii) Decrease of monetary and foreign exchange updates (R$ 1 million);
The main factors that affected the financial expense (decrease of R$ 1 million) were:
(iii) Increase of debt charges, mainly due to the increase in the reference rates (R$ 12 million);
(iv) Reduction in capitalized interest (R$ 9 million), due to the commercial start-up of the generation projects that were under construction;
Partially offset by:
(v) Reduction in other financial expenses (R$ 4 million);
(vi) Decrease of monetary and foreign exchange updates (R$ 1 million).
In 1Q17, Net Loss was of R$ 50 million, compared to a net income of R$ 107 million in 1Q16 (R$ 99 million).
Página 49 de 64
On the date of this report, the portfolio of projects of CPFL Renováveis (100% Participation) totaled 2,054 MW of operating installed capacity and 75 MW of capacity under construction. The operational power plants comprises 39 Small Hydroelectric Power Plants – SHPPs (423 MW), 43 wind farms (1,260 MW), 8 biomass thermoelectric power plants (370 MW) and 1 solar power plant (1 MW). Still under construction there are 2 wind farms (48 MW) and 1 SHPP (27 MW).
Additionally, CPFL Renováveis owns wind and SHPP projects under development totaling 2,987 MW, representing a total portfolio of 5,115 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 |
1,260 |
1 |
2,054 |
Under construction |
27 |
- |
48 |
- |
75 |
Under development |
216 |
- |
2,226 |
544 |
2,987 |
Total |
666 |
370 |
3,535 |
545 |
5,115 |
Pedra Cheirosa Wind Farms
The wind farms of Pedra Cheirosa Complex (Pedra Cheirosa I and II), located in the State of Ceará, are under construction. Start-up is scheduled for 1H18. The installed capacity is of 48.3 MW and the assured energy is of 26.1 average-MW. Energy was sold through long-term contract in the 2013 A-5 auction (Pedra Cheirosa I – price: R$ 156.20/MWh | Pedra Cheirosa II – price: R$ 156.82, both in March 2017).
Boa Vista II SHPP
The Boa Vista II SHPP, project located in the State of Minas Gerais, has operations in input prediction from 1Q20. The installed capacity is of 26.5 MW and the assured energy is of 14.8 average-MW. Energy was sold through long-term contracts in the 2015 A-5 new energy auction (price: R$ 225.53/MWh – March 2017).
Página 50 de 64
(R$ thousands)
Consolidated | |||
ASSETS |
03/31/2017 |
12/31/2016 |
03/31/2016 |
CURRENT |
|||
Cash and Cash Equivalents |
4,877,813 |
6,164,997 |
4,405,794 |
Consumers, Concessionaries and Licensees |
4,065,465 |
3,765,893 |
3,726,057 |
Dividend and Interest on Equity |
75,395 |
73,328 |
86,901 |
Financial Investments |
450 |
449 |
12,664 |
Recoverable Taxes |
423,054 |
403,848 |
479,172 |
Derivatives |
197,741 |
163,241 |
604,591 |
Sectoral Financial Assets |
- |
- |
903,262 |
Concession Financial Assets |
10,836 |
10,700 |
9,861 |
Other Credits |
911,796 |
796,731 |
1,085,302 |
TOTAL CURRENT |
10,562,550 |
11,379,187 |
11,313,605 |
NON-CURRENT |
|||
Consumers, Concessionaries and Licensees |
204,416 |
203,185 |
136,400 |
Affiliates, Subsidiaries and Parent Company |
9,236 |
47,631 |
87,077 |
Judicial Deposits |
769,646 |
550,072 |
489,460 |
Recoverable Taxes |
205,938 |
198,286 |
168,455 |
Sectoral Financial Assets |
- |
- |
- |
Derivatives |
440,011 |
641,357 |
1,240,428 |
Deferred Taxes |
935,471 |
922,858 |
413,858 |
Concession Financial Assets |
5,601,969 |
5,363,144 |
3,834,678 |
Investments at Cost |
116,654 |
116,654 |
116,654 |
Other Credits |
795,499 |
766,253 |
618,997 |
Investments |
1,487,245 |
1,493,753 |
1,315,601 |
Property, Plant and Equipment |
9,880,291 |
9,712,998 |
9,284,969 |
Intangible |
10,723,398 |
10,775,613 |
9,085,331 |
TOTAL NON-CURRENT |
31,169,774 |
30,791,805 |
26,791,909 |
TOTAL ASSETS |
41,732,324 |
42,170,992 |
38,105,514 |
Página 51 de 64
(R$ thousands)
|
Consolidated | ||
LIABILITIES AND SHAREHOLDERS' EQUITY |
03/31/2017 |
12/31/2016 |
03/31/2016 |
CURRENT |
|||
Suppliers |
2,232,237 |
2,728,130 |
1,873,994 |
Accrued Interest on Debts |
113,733 |
129,364 |
62,658 |
Accrued Interest on Debentures |
325,169 |
305,180 |
216,035 |
Loans and Financing |
2,826,371 |
1,746,284 |
2,303,027 |
Debentures |
1,119,269 |
1,242,095 |
220,576 |
Employee Pension Plans |
44,016 |
33,209 |
200 |
Regulatory Charges |
339,777 |
366,078 |
733,451 |
Taxes, Fees and Contributions |
785,682 |
681,544 |
709,205 |
Dividend and Interest on Equity |
19,970 |
232,851 |
220,534 |
Accrued Liabilities |
127,680 |
131,707 |
90,917 |
Derivatives |
7,581 |
6,055 |
35,125 |
Sectoral Financial Liabilities |
1,316,071 |
597,515 |
- |
Public Utilities |
10,857 |
10,857 |
9,921 |
Other Accounts Payable |
892,000 |
807,623 |
878,932 |
TOTAL CURRENT |
10,160,412 |
9,018,492 |
7,354,576 |
NON-CURRENT |
|||
Suppliers |
130,767 |
129,781 |
633 |
Accrued Interest on Debts |
139,342 |
144,709 |
137,405 |
Accrued Interest on Debentures |
33,203 |
29,153 |
19,408 |
Loans and Financing |
9,226,883 |
11,023,685 |
11,006,688 |
Debentures |
7,546,014 |
7,423,519 |
6,271,237 |
Employee Pension Plans |
1,011,715 |
1,019,233 |
469,064 |
Taxes, Fees and Contributions |
25,096 |
26,814 |
- |
Deferred Taxes |
1,286,397 |
1,324,134 |
1,415,799 |
Reserve for Tax, Civil and Labor Risks |
837,809 |
833,276 |
598,349 |
Derivatives |
165,825 |
112,207 |
14,534 |
Sectoral Financial Liabilities |
209,384 |
317,406 |
196,536 |
Public Utilities |
87,404 |
86,624 |
84,226 |
Other Accounts Payable |
278,850 |
309,292 |
179,179 |
TOTAL NON-CURRENT |
20,978,689 |
22,779,832 |
20,393,058 |
SHAREHOLDERS' EQUITY |
|||
Capital |
5,741,284 |
5,741,284 |
5,348,312 |
Capital Reserve |
468,014 |
468,014 |
468,082 |
Legal Reserve |
739,102 |
739,102 |
694,058 |
Statutory Reserve - Concession Financial Assets |
729,608 |
702,928 |
640,545 |
Statutory Reserve - Strengthening of Working Capital |
545,505 |
545,505 |
392,972 |
Adittional Dividend Proposed |
- |
7,820 |
- |
Other Comprehensive Income |
(241,043) |
(234,633) |
177,537 |
Retained Earnings |
225,616 |
- |
222,712 |
8,208,086 |
7,970,021 |
7,944,217 | |
Non-Controlling Shareholders' Interest |
2,385,137 |
2,402,648 |
2,413,663 |
TOTAL SHAREHOLDERS' EQUITY |
10,593,224 |
10,372,668 |
10,357,881 |
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY |
41,732,324 |
42,170,992 |
38,105,514 |
Página 52 de 64
(R$ thousands)
Consolidated | ||||
|
|
1Q17 |
1Q16 |
Variation |
OPERATING REVENUES |
|
|||
Electricity Sales to Final Customers |
|
6,821,851 |
6,463,078 |
5.6% |
Electricity Sales to Distributors |
|
950,802 |
748,256 |
27.1% |
Revenue from building the infrastructure |
|
416,039 |
217,134 |
91.6% |
Update of concession's financial asset |
|
48,923 |
87,380 |
-44.0% |
Sectorial financial assets and liabilities |
|
(565,003) |
(732,253) |
-22.8% |
Other Operating Revenues |
|
1,057,772 |
802,052 |
31.9% |
|
8,730,385 |
7,585,647 |
15.1% | |
|
||||
DEDUCTIONS FROM OPERATING REVENUES |
|
(3,191,606) |
(3,248,878) |
-1.8% |
NET OPERATING REVENUES |
|
5,538,779 |
4,336,770 |
27.7% |
|
||||
COST OF ELECTRIC ENERGY SERVICES |
|
|||
Electricity Purchased for Resale |
|
(3,018,384) |
(2,165,933) |
39.4% |
Electricity Network Usage Charges |
|
(202,270) |
(362,089) |
-44.1% |
|
(3,220,654) |
(2,528,021) |
27.4% | |
OPERATING COSTS AND EXPENSES |
|
|||
Personnel |
|
(332,483) |
(244,968) |
35.7% |
Material |
|
(55,095) |
(39,785) |
38.5% |
Outsourced Services |
|
(185,253) |
(149,219) |
24.1% |
Other Operating Costs/Expenses |
|
(185,924) |
(172,685) |
7.7% |
Allowance for Doubtful Accounts |
|
(46,696) |
(46,051) |
1.4% |
Legal and judicial expenses |
|
(55,119) |
(59,384) |
-7.2% |
Others |
|
(84,109) |
(67,249) |
25.1% |
Cost of building the infrastructure |
|
(414,627) |
(217,035) |
91.0% |
Employee Pension Plans |
|
(28,831) |
(13,913) |
107.2% |
Depreciation and Amortization |
|
(304,323) |
(246,081) |
23.7% |
Amortization of Concession's Intangible |
|
(72,116) |
(61,887) |
16.5% |
|
(1,578,653) |
(1,145,572) |
37.8% | |
|
||||
EBITDA1 |
|
1,195,765 |
1,034,769 |
15.6% |
|
||||
INCOME FROM ELECTRIC ENERGY SERVICE |
|
739,472 |
663,176 |
11.5% |
|
||||
FINANCIAL REVENUES (EXPENSES) |
|
|||
Financial Revenues |
|
280,711 |
312,332 |
-10.1% |
Financial Expenses |
|
(716,850) |
(631,359) |
13.5% |
|
(436,138) |
(319,027) |
36.7% | |
|
||||
EQUITY ACCOUNTING |
|
|||
Equity Accounting |
|
79,854 |
63,625 |
25.5% |
Assets Surplus Value Amortization |
|
(145) |
(145) |
0.0% |
|
79,709 |
63,480 |
25.6% | |
|
||||
INCOME BEFORE TAXES ON INCOME |
|
383,043 |
407,629 |
-6.0% |
|
||||
Social Contribution |
|
(40,575) |
(47,166) |
-14.0% |
Income Tax |
(110,347) |
(128,016) |
-13.8% | |
|
||||
NET INCOME |
|
232,121 |
232,446 |
-0.1% |
Controlling Shareholders' Interest |
|
245,886 |
271,349 |
-9.4% |
Non-Controlling Shareholders' Interest |
|
(13,765) |
(38,902) |
-64.6% |
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 53 de 64
(R$ thousands)
Consolidated | ||||
1Q17 |
Last 12M | |||
Beginning Balance |
6,164,997 |
4,405,795 | ||
Net Income Before Taxes |
383,043 |
1,355,961 | ||
Depreciation and Amortization |
376,718 |
1,359,915 | ||
Interest on Debts and Monetary and Foreign Exchange Restatements |
592,962 |
2,258,620 | ||
Consumers, Concessionaries and Licensees |
(347,285) |
50,777 | ||
Sectoral Financial Assets |
20,486 |
1,341,471 | ||
Accounts Receivable - Resources Provided by the CDE/CCEE |
(70,265) |
299,563 | ||
Suppliers |
(479,421) |
24,832 | ||
Sectoral Financial Liabilities |
562,875 |
729,667 | ||
Accounts Payable - CDE |
(7,545) |
(53,288) | ||
Interest on Debts and Debentures Paid |
(457,262) |
(1,581,730) | ||
Income Tax and Social Contribution Paid |
(152,233) |
(935,442) | ||
Others |
(149,785) |
(292,335) | ||
(110,755) |
3,202,050 | |||
Total Operating Activities |
272,288 |
4,558,011 | ||
Investment Activities |
||||
Value Paid in Business Combination, Net of the Acquired Cash |
- |
(1,496,675) | ||
Acquisition of Property, Plant and Equipment, and Intangibles |
(642,319) |
(2,434,381) | ||
Others |
(35,436) |
(93,323) | ||
Total Investment Activities |
(677,755) |
(4,024,379) | ||
Financing Activities |
||||
Capital Increase by Non Controlling Shareholders |
- |
467 | ||
Loans and Debentures |
801,737 |
4,158,904 | ||
Principal Amortization of Loans and Debentures, Net of Derivatives |
(1,479,465) |
(3,784,902) | ||
Dividend and Interest on Equity Paid |
(224,437) |
(451,488) | ||
Others |
20,448 |
15,405 | ||
Total Financing Activities |
(881,717) |
(61,614) | ||
Cash Flow Generation |
(1,287,184) |
472,018 | ||
Ending Balance - 03/31/2017 |
|
4,877,813 |
|
4,877,813 |
Página 54 de 64
(R$ thousands)
Conventional Generation |
|
|
|
|
1Q17 |
1Q16 |
Var. |
OPERATING REVENUE |
|
|
|
Eletricity Sales to Final Consumers |
- |
- |
- |
Eletricity Sales to Distributors |
279,499 |
259,272 |
7.8% |
Other Operating Revenues |
2,818 |
1,682 |
67.5% |
|
282,317 |
260,954 |
8.2% |
|
|
|
|
DEDUCTIONS FROM OPERATING REVENUE |
(25,166) |
(24,157) |
4.2% |
NET OPERATING REVENUE |
257,151 |
236,797 |
8.6% |
|
|
|
|
COST OF ELETRIC ENERGY SERVICES |
|
|
|
Eletricity Purchased for Resale |
(15,394) |
(19,814) |
-22.3% |
Eletricity Network Usage Charges |
(6,579) |
(5,852) |
12.4% |
|
(21,973) |
(25,666) |
-14.4% |
OPERATING COSTS AND EXPENSES |
|
|
|
Personnel |
(10,085) |
(9,022) |
11.8% |
Material |
(550) |
(847) |
-35.0% |
Outsourced Services |
(5,487) |
(4,636) |
18.4% |
Other Operating Costs/Expenses |
(8,595) |
(10,915) |
-21.3% |
Employee Pension Plans |
(517) |
(322) |
60.7% |
Depreciation and Amortization |
(28,173) |
(28,305) |
-0.5% |
Amortization of Concession's Intangible |
(2,492) |
(2,492) |
0.0% |
|
(55,899) |
(56,538) |
-1.1% |
|
|
|
|
EBITDA |
289,654 |
248,869 |
16.4% |
|
|
|
|
EBIT |
179,279 |
154,592 |
16.0% |
|
|
|
|
FINANCIAL INCOME (EXPENSE) |
|
|
|
Financial Income |
50,508 |
44,851 |
12.6% |
Financial Expenses |
(150,573) |
(128,587) |
17.1% |
Interest on Equity |
- |
- |
- |
|
(100,065) |
(83,736) |
19.5% |
|
|
|
|
EQUITY ACCOUNTING |
|
|
|
Equity Accounting |
79,709 |
63,480 |
25.6% |
Assets Surplus Value Amortization |
- |
- |
0.0% |
|
79,709 |
63,480 |
25.6% |
|
|
|
|
INCOME BEFORE TAXES ON INCOME |
158,924 |
134,336 |
18.3% |
|
|
|
|
Social Contribution |
(7,168) |
(6,605) |
8.5% |
Income Tax |
(20,156) |
(18,135) |
11.1% |
|
|
|
|
NET INCOME (LOSS) |
131,599 |
109,596 |
20.1% |
Página 55 de 64
(R$ thousands)
Consolidated (100% Participation) | |||
|
1Q17 |
1Q16 |
Var. % |
OPERATING REVENUES |
| ||
Eletricity Sales to Final Consumers |
23,790 |
23,200 |
2.5% |
Eletricity Sales to Distributors |
384,169 |
284,175 |
35.2% |
Other Operating Revenues |
885 |
309 |
186.2% |
|
408,844 |
307,685 |
32.9% |
|
| ||
DEDUCTIONS FROM OPERATING REVENUES |
(21,382) |
(16,771) |
27.5% |
NET OPERATING REVENUES |
387,462 |
290,914 |
33.2% |
|
| ||
COST OF ELETRIC ENERGY SERVICES |
| ||
Eletricity Purchased for Resale |
(27,298) |
(13,134) |
107.8% |
Eletricity Network Usage Charges |
(23,892) |
(18,236) |
31.0% |
|
(51,191) |
(31,370) |
63.2% |
OPERATING COSTS AND EXPENSES |
| ||
Personnel |
(22,910) |
(20,335) |
12.7% |
Material |
(4,878) |
(3,511) |
38.9% |
Outsourced Services |
(46,278) |
(42,096) |
9.9% |
Other Operating Costs/Expenses |
(25,735) |
(25,885) |
-0.6% |
Depreciation and Amortization |
(112,208) |
(95,497) |
17.5% |
Amortization of Concession's Intangible |
(38,625) |
(37,800) |
2.2% |
|
(250,634) |
(225,124) |
11.3% |
|
|
|
|
EBITDA (1) |
236,470 |
167,717 |
41.0% |
|
| ||
EBIT |
85,637 |
34,419 |
148.8% |
|
| ||
FINANCIAL INCOME (EXPENSE) |
| ||
Financial Income |
38,890 |
29,880 |
30.2% |
Financial Expenses |
(162,541) |
(163,959) |
-0.9% |
|
(123,651) |
(134,079) |
-7.8% |
|
| ||
INCOME BEFORE TAXES ON INCOME |
(38,014) |
(99,660) |
-61.9% |
|
| ||
Social Contribution |
(4,573) |
(2,925) |
56.3% |
Income Tax |
(7,573) |
(4,296) |
76.3% |
|
|
|
|
NET INCOME |
(50,160) |
(106,881) |
-53.1% |
Página 56 de 64
(R$ thousands)
Consolidated | ||||
|
|
1Q17 |
1Q16 |
Variation |
OPERATING REVENUE |
||||
Electricity Sales to Final Customers |
6,361,528 |
6,124,109 |
3.9% | |
Electricity Sales to Distributors |
285,534 |
215,538 |
32.5% | |
Revenue from building the infrastructure |
378,442 |
214,423 |
76.5% | |
Adjustments to the concession´s financial asset |
48,923 |
87,380 |
-44.0% | |
Sectoral financial assets and liabilities |
(565,003) |
(732,253) |
-22.8% | |
Other Operating Revenues |
1,026,210 |
776,395 |
32.2% | |
|
7,535,635 |
6,685,592 |
12.7% | |
|
|
|
|
|
DEDUCTIONS FROM OPERATING REVENUE |
(3,073,282) |
(3,158,707) |
-2.7% | |
NET OPERATING REVENUE |
4,462,353 |
3,526,884 |
26.5% | |
|
||||
COST OF ELECTRIC ENERGY SERVICES |
||||
Electricity Purchased for Resale |
(2,632,925) |
(1,882,032) |
39.9% | |
Electricity Network Usage Charges |
(177,459) |
(343,437) |
-48.3% | |
|
(2,810,384) |
(2,225,468) |
26.3% | |
OPERATING COSTS AND EXPENSES |
|
|||
Personnel |
|
(223,800) |
(165,749) |
35.0% |
Material |
|
(38,810) |
(28,315) |
37.1% |
Outsourced Services |
|
(194,435) |
(144,128) |
34.9% |
Other Operating Costs/Expenses |
|
(162,323) |
(144,345) |
12.5% |
Allowance for Doubtful Accounts |
|
(46,977) |
(45,374) |
3.5% |
Legal and Judicial Expenses |
|
(45,827) |
(50,533) |
-9.3% |
Others |
|
(69,519) |
(48,438) |
43.5% |
Cost of building the infrastructure |
|
(378,442) |
(214,423) |
76.5% |
Employee Pension Plans |
|
(28,315) |
(13,591) |
108.3% |
Depreciation and Amortization |
|
(151,151) |
(118,085) |
28.0% |
Amortization of Concession's Intangible |
|
(15,322) |
(5,918) |
158.9% |
Amortization of goodwill derived from acquisition |
|
(22,202) |
(15,035) |
47.7% |
|
(1,214,798) |
(849,587) |
43.0% | |
|
||||
EBITDA (IFRS)(1) |
|
625,845 |
590,866 |
5.9% |
|
||||
EBIT |
|
437,171 |
451,829 |
-3.2% |
|
||||
FINANCIAL INCOME (EXPENSE) |
|
|||
Financial Income |
|
177,342 |
218,543 |
-18.9% |
Financial Expenses |
|
(358,958) |
(309,554) |
16.0% |
Interest on Equity |
|
|||
|
(181,616) |
(91,011) |
99.6% | |
|
||||
INCOME BEFORE TAXES ON INCOME |
|
255,554 |
360,818 |
-29.2% |
|
||||
Social Contribution |
|
(28,077) |
(36,746) |
-23.6% |
Income Tax |
|
(77,273) |
(102,051) |
-24.3% |
|
||||
Net Income (IFRS) |
|
150,205 |
222,021 |
-32.3% |
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 57 de 64
(R$ thousands)
Consolidated (without RGE Sul) | ||||
|
|
1Q17 |
1Q16 |
Variation |
OPERATING REVENUE |
||||
Electricity Sales to Final Customers |
5,197,280 |
6,124,109 |
-15.1% | |
Electricity Sales to Distributors |
267,893 |
215,538 |
24.3% | |
Revenue from building the infrastructure |
293,779 |
214,423 |
37.0% | |
Adjustments to the concession´s financial asset |
40,784 |
87,380 |
-53.3% | |
Sectoral financial assets and liabilities |
(448,354) |
(732,253) |
-38.8% | |
Other Operating Revenues |
840,509 |
776,395 |
8.3% | |
|
6,191,890 |
6,685,592 |
-7.4% | |
|
|
|
|
|
DEDUCTIONS FROM OPERATING REVENUE |
(2,496,035) |
(3,158,707) |
-21.0% | |
NET OPERATING REVENUE |
3,695,855 |
3,526,884 |
4.8% | |
|
||||
COST OF ELECTRIC ENERGY SERVICES |
||||
Electricity Purchased for Resale |
(2,213,757) |
(1,882,032) |
17.6% | |
Electricity Network Usage Charges |
(139,658) |
(343,437) |
-59.3% | |
|
(2,353,415) |
(2,225,468) |
5.7% | |
OPERATING COSTS AND EXPENSES |
|
|||
Personnel |
|
(182,292) |
(165,749) |
10.0% |
Material |
|
(30,086) |
(28,315) |
6.3% |
Outsourced Services |
|
(163,302) |
(144,128) |
13.3% |
Other Operating Costs/Expenses |
|
(139,113) |
(144,345) |
-3.6% |
Allowance for Doubtful Accounts |
|
(38,951) |
(45,374) |
-14.2% |
Legal and Judicial Expenses |
|
(44,127) |
(50,533) |
-12.7% |
Others |
|
(56,035) |
(48,438) |
15.7% |
Cost of building the infrastructure |
|
(293,779) |
(214,423) |
37.0% |
Employee Pension Plans |
|
(25,499) |
(13,591) |
87.6% |
Depreciation and Amortization |
|
(122,361) |
(118,085) |
3.6% |
Amortization of Concession's Intangible |
|
(5,918) |
(5,918) |
0.0% |
Amortization of goodwill derived from acquisition |
|
(15,035) |
(15,035) |
0.0% |
|
(977,385) |
(849,587) |
15.0% | |
|
||||
EBITDA(1) |
|
508,369 |
590,866 |
-14.0% |
|
||||
EBIT |
|
365,056 |
451,829 |
-19.2% |
|
||||
FINANCIAL INCOME (EXPENSE) |
|
|||
Financial Income |
|
155,569 |
218,543 |
-28.8% |
Financial Expenses |
|
(309,388) |
(309,554) |
-0.1% |
Interest on Equity |
|
|||
|
(153,819) |
(91,011) |
69.0% | |
|
||||
INCOME BEFORE TAXES ON INCOME |
|
211,237 |
360,818 |
-41.5% |
|
||||
Social Contribution |
|
(23,316) |
(36,746) |
-36.5% |
Income Tax |
|
(64,228) |
(102,051) |
-37.1% |
|
||||
Net Income |
|
123,693 |
222,021 |
-44.3% |
Note: (1) EBITDA is calculated from the sum of net income, taxes, financial result and depreciation/amortization, as CVM Instruction no. 527/12.
Página 58 de 64
(R$ thousands)
Summary of Income Statement by Distribution Company (R$ Thousands) | |||
CPFL PAULISTA | |||
|
1Q17 |
1Q16 |
Var. |
Gross Operating Revenue |
3,206,368 |
3,426,287 |
-6.4% |
Net Operating Revenue |
1,892,227 |
1,807,781 |
4.7% |
Cost of Electric Power |
(1,240,578) |
(1,177,354) |
5.4% |
Operating Costs & Expenses |
(490,483) |
(423,936) |
15.7% |
EBIT |
161,165 |
206,492 |
-22.0% |
EBITDA (1) |
217,374 |
258,863 |
-16.0% |
Financial Income (Expense) |
(72,602) |
(40,489) |
79.3% |
Income Before Taxes |
88,563 |
166,003 |
-46.6% |
Net Income |
52,268 |
104,295 |
-49.9% |
CPFL PIRATININGA | |||
|
1Q17 |
1Q16 |
Var. |
Gross Operating Revenue |
1,415,587 |
1,587,552 |
-10.8% |
Net Operating Revenue |
849,889 |
803,292 |
5.8% |
Cost of Electric Power |
(576,675) |
(521,982) |
10.5% |
Operating Costs & Expenses |
(190,166) |
(150,960) |
26.0% |
EBIT |
83,049 |
130,350 |
-36.3% |
EBITDA (1) |
106,906 |
153,222 |
-30.2% |
Financial Income (Expense) |
(32,505) |
(20,176) |
61.1% |
Income Before Taxes |
50,544 |
110,175 |
-54.1% |
Net Income |
31,363 |
68,383 |
-54.1% |
RGE | |||
|
1Q17 |
1Q16 |
Var. |
Gross Operating Revenue |
1,215,435 |
1,309,502 |
-7.2% |
Net Operating Revenue |
728,517 |
709,202 |
2.7% |
Cost of Electric Power |
(417,453) |
(413,326) |
1.0% |
Operating Costs & Expenses |
(211,525) |
(200,073) |
5.7% |
EBIT |
99,539 |
95,804 |
3.9% |
EBITDA (1) |
139,124 |
133,565 |
4.2% |
Financial Income (Expense) |
(37,486) |
(19,741) |
89.9% |
Income Before Taxes |
62,053 |
76,063 |
-18.4% |
Net Income |
39,555 |
49,149 |
-19.5% |
CPFL SANTA CRUZ | |||
|
1Q17 |
1Q16 |
Var. |
Gross Operating Revenue |
159,595 |
155,251 |
2.8% |
Net Operating Revenue |
102,760 |
88,093 |
16.6% |
Cost of Electric Power |
(54,577) |
(47,580) |
14.7% |
Operating Costs & Expenses |
(30,064) |
(25,941) |
15.9% |
EBIT |
18,119 |
14,573 |
24.3% |
EBITDA (1) |
22,418 |
19,147 |
17.1% |
Financial Income (Expense) |
(3,356) |
(4,297) |
-21.9% |
Income Before Taxes |
14,762 |
10,276 |
43.7% |
Net Income |
9,321 |
6,514 |
43.1% |
Note:
Página 59 de 64
(1) EBITDA (IFRS) is calculated from the sum of net income, taxes, financial result and depreciation/amortization.
Summary of Income Statement by Distribution Company (R$ Thousands) | |||
CPFL LESTE PAULISTA | |||
|
1Q17 |
1Q16 |
Var. |
Gross Operating Revenue |
46,196 |
43,664 |
5.8% |
Net Operating Revenue |
30,552 |
25,698 |
18.9% |
Cost of Electric Power |
(14,258) |
(13,584) |
5.0% |
Operating Costs & Expenses |
(10,439) |
(8,848) |
18.0% |
EBIT |
5,854 |
3,266 |
79.3% |
EBITDA (1) |
7,474 |
4,976 |
50.2% |
Financial Income (Expense) |
(1,779) |
(2,125) |
-16.3% |
Income Before Taxes |
4,075 |
1,140 |
257.4% |
Net Income |
2,561 |
686 |
273.1% |
CPFL SUL PAULISTA | |||
|
1Q17 |
1Q16 |
Var. |
Gross Operating Revenue |
60,734 |
63,239 |
-4.0% |
Net Operating Revenue |
39,578 |
36,776 |
7.6% |
Cost of Electric Power |
(19,574) |
(19,789) |
-1.1% |
Operating Costs & Expenses |
(13,983) |
(11,863) |
17.9% |
EBIT |
6,021 |
5,123 |
17.5% |
EBITDA (1) |
6,549 |
7,415 |
-11.7% |
Financial Income (Expense) |
(2,437) |
(2,085) |
16.9% |
Income Before Taxes |
3,585 |
3,039 |
18.0% |
Net Income |
2,207 |
1,926 |
14.6% |
CPFL JAGUARI | |||
|
1Q17 |
1Q16 |
Var. |
Gross Operating Revenue |
54,898 |
65,577 |
-16.3% |
Net Operating Revenue |
31,334 |
35,391 |
-11.5% |
Cost of Electric Power |
(20,326) |
(22,317) |
-8.9% |
Operating Costs & Expenses |
(8,826) |
(6,005) |
47.0% |
EBIT |
2,182 |
7,069 |
-69.1% |
EBITDA (1) |
3,209 |
8,185 |
-60.8% |
Financial Income (Expense) |
(2,499) |
(1,171) |
113.4% |
Income Before Taxes |
(317) |
5,898 |
-105.4% |
Net Income |
(392) |
3,746 |
-110.5% |
CPFL MOCOCA | |||
|
1Q17 |
1Q16 |
Var. |
Gross Operating Revenue |
33,077 |
34,519 |
-4.2% |
Net Operating Revenue |
20,998 |
20,651 |
1.7% |
Cost of Electric Power |
(9,973) |
(9,537) |
4.6% |
Operating Costs & Expenses |
(6,864) |
(6,927) |
-0.9% |
EBIT |
4,161 |
4,187 |
-0.6% |
EBITDA (1) |
5,315 |
5,494 |
-3.3% |
Financial Income (Expense) |
(1,036) |
(1,671) |
-38.0% |
Income Before Taxes |
3,126 |
2,515 |
24.3% |
Net Income |
1,965 |
1,613 |
21.8% |
Note:
Página 60 de 64
(1) EBITDA (IFRS) is calculated from the sum of net income, taxes, financial result and depreciation/amortization.
Summary of Income Statement by Distribution Company (R$ Thousands) | |||
RGE SUL | |||
|
1Q17 |
1Q16 |
Var. |
Gross Operating Revenue |
1,343,745 |
- |
0.0% |
Net Operating Revenue |
766,497 |
- |
0.0% |
Cost of Electric Power |
(456,969) |
- |
0.0% |
Operating Costs & Expenses |
(237,414) |
- |
0.0% |
EBIT |
72,115 |
- |
0.0% |
EBITDA (1) |
117,477 |
- |
0.0% |
Financial Income (Expense) |
(27,798) |
- |
0.0% |
Income Before Taxes |
44,317 |
- |
0.0% |
Net Income |
26,512 |
- |
0.0% |
Note:
(1) EBITDA (IFRS) is calculated from the sum of net income, taxes, financial result and depreciation/amortization.
Página 61 de 64
CPFL Paulista | |||
|
1Q17 |
1Q16 |
Var. |
Residential |
2,392 |
2,360 |
1.3% |
Industrial |
2,532 |
2,546 |
-0.6% |
Commercial |
1,455 |
1,476 |
-1.4% |
Others |
1,033 |
994 |
3.9% |
Total |
7,411 |
7,376 |
0.5% |
CPFL Piratininga | |||
|
1Q17 |
1Q16 |
Var. |
Residential |
1,051 |
1,042 |
0.8% |
Industrial |
1,483 |
1,600 |
-7.3% |
Commercial |
647 |
640 |
1.1% |
Others |
282 |
279 |
1.2% |
Total |
3,463 |
3,562 |
-2.8% |
RGE | |||
|
1Q17 |
1Q16 |
Var. |
Residential |
686 |
665 |
3.2% |
Industrial |
792 |
764 |
3.7% |
Commercial |
371 |
377 |
-1.7% |
Others |
758 |
724 |
4.7% |
Total |
2,607 |
2,530 |
3.0% |
CPFL Santa Cruz | |||
|
1Q17 |
1Q16 |
Var. |
Residential |
94 |
93 |
1.0% |
Industrial |
51 |
55 |
-6.1% |
Commercial |
44 |
43 |
0.5% |
Others |
90 |
85 |
5.7% |
Total |
279 |
276 |
0.9% |
CPFL Jaguari | |||
|
1Q17 |
1Q16 |
Var. |
Residential |
23 |
23 |
0.8% |
Industrial |
94 |
99 |
-4.4% |
Commercial |
14 |
13 |
8.3% |
Others |
9 |
10 |
-2.5% |
Total |
141 |
145 |
-2.3% |
CPFL Mococa | |||
|
1Q17 |
1Q16 |
Var. |
Residential |
20 |
19 |
1.1% |
Industrial |
15 |
16 |
-3.9% |
Commercial |
8 |
8 |
-2.9% |
Others |
15 |
14 |
5.7% |
Total |
57 |
57 |
0.3% |
CPFL Leste Paulista | |||
|
1Q17 |
1Q16 |
Var. |
Residential |
26 |
26 |
0.6% |
Industrial |
22 |
21 |
4.8% |
Commercial |
12 |
12 |
-1.6% |
Others |
25 |
22 |
15.5% |
Total |
85 |
80 |
5.4% |
CPFL Sul Paulista | |||
|
1Q17 |
1Q16 |
Var. |
Residential |
37 |
37 |
0.8% |
Industrial |
45 |
47 |
-2.6% |
Commercial |
16 |
15 |
3.3% |
Others |
24 |
23 |
4.4% |
Total |
122 |
122 |
0.5% |
RGE Sul (*) | |||
|
1Q17 |
1Q16 |
Var. |
Residential |
800 |
- |
0.0% |
Industrial |
628 |
- |
0.0% |
Commercial |
378 |
- |
0.0% |
Others |
742 |
- |
0.0% |
Total |
2,549 |
- |
0.0% |
Note: (*) Considers sales within the concession area from 1Q17.
Página 62 de 64
CPFL Paulista | |||
|
1Q17 |
1Q16 |
Var. |
Residential |
2,392 |
2,360 |
1.3% |
Industrial |
688 |
884 |
-22.2% |
Commercial |
1,161 |
1,326 |
-12.4% |
Others |
994 |
961 |
3.4% |
Total |
5,235 |
5,531 |
-5.4% |
CPFL Piratininga | |||
|
1Q17 |
1Q16 |
Var. |
Residential |
1,051 |
1,042 |
0.8% |
Industrial |
322 |
463 |
-30.4% |
Commercial |
507 |
569 |
-10.9% |
Others |
249 |
268 |
-7.2% |
Total |
2,129 |
2,342 |
-9.1% |
RGE | |||
|
1Q17 |
1Q16 |
Var. |
Residential |
686 |
665 |
3.2% |
Industrial |
288 |
349 |
-17.4% |
Commercial |
345 |
360 |
-4.2% |
Others |
754 |
724 |
4.2% |
Total |
2,073 |
2,097 |
-1.2% |
CPFL Santa Cruz | |||
|
1Q17 |
1Q16 |
Var. |
Residential |
94 |
93 |
1.0% |
Industrial |
26 |
43 |
-37.8% |
Commercial |
41 |
43 |
-6.4% |
Others |
90 |
85 |
5.7% |
Total |
251 |
264 |
-5.0% |
CPFL Jaguari | |||
|
1Q17 |
1Q16 |
Var. |
Residential |
23 |
23 |
0.8% |
Industrial |
52 |
72 |
-27.7% |
Commercial |
14 |
13 |
8.3% |
Others |
9 |
10 |
-2.5% |
Total |
99 |
118 |
-16.0% |
CPFL Mococa | |||
|
1Q17 |
1Q16 |
Var. |
Residential |
20 |
19 |
1.1% |
Industrial |
8 |
8 |
0.5% |
Commercial |
8 |
8 |
-4.3% |
Others |
15 |
14 |
5.7% |
Total |
51 |
50 |
1.4% |
CPFL Leste Paulista | |||
|
1Q17 |
1Q16 |
Var. |
Residential |
26 |
26 |
0.6% |
Industrial |
7 |
7 |
5.0% |
Commercial |
12 |
12 |
-1.6% |
Others |
25 |
22 |
15.5% |
Total |
70 |
66 |
5.6% |
CPFL Sul Paulista | |||
|
1Q17 |
1Q16 |
Var. |
Residential |
37 |
37 |
0.8% |
Industrial |
25 |
24 |
5.2% |
Commercial |
16 |
15 |
3.3% |
Others |
24 |
23 |
4.4% |
Total |
102 |
99 |
3.1% |
RGE Sul (*) | |||
|
1Q17 |
1Q16 |
Var. |
Residential |
800 |
- |
0.0% |
Industrial |
214 |
- |
0.0% |
Commercial |
339 |
- |
0.0% |
Others |
741 |
- |
0.0% |
Total |
2,095 |
- |
0.0% |
Note: (*) Considers sales to the captive market from 1Q17.
Página 63 de 64
(in R$ million)
Notes:
1) In accordance with financial covenants calculation in cases of assets acquired by the Company.
Página 64 de 64
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.